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Jackson - S. 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Signage Rebranding Costsferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2022-01-012022-12-31 C008999 EMI New Nuclear, LLC 2022-01-012022-12-31 C008999 2022-Grenada-Grenada-2L02-Milwaukeeferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Deferred Electric Storm Restoration Costs 2022-01-012022-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2022-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMember 2022-12-31 C008999 RIDGELAND, Distribution, Unattended 2022-01-012022-12-31 C008999 GLOSTER, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:LocalTaxMember 2022-01-012022-12-31 C008999 ferc:OtherTaxesAndFeesMember 2022-01-012022-12-31 C008999 SL-37 Municipal Street Lighting 2022-01-012022-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024ferc:ElectricUtilityMember 2022-12-31 C008999 Crenshaw: Add Circuit Switcher 2022-01-012022-12-31 C008999 Other 2022-01-012022-12-31 C008999 ScheduleExtraordinaryPropertyLossesAbstract 2022-01-012022-12-31 C008999 GRENADA, Distribution, Unattended 2022-01-012022-12-31 C008999 EML: Camlin Pilot - Baxter Wilsonferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 HORN LAKE, Transmission, Unattended 2022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember EMI New Nuclear, LLC 2022-12-31 C008999 CATLETT, SOUTH CANTON 230 - [2392], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 Greenbrook to Snowden Park 115kv Lnferc:ElectricUtilityMember 2022-12-31 C008999 MCADAMS, LAKEOVER 500 - [6960], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 UPIC-Hernando-Laughter Road S-Milleferc:ElectricUtilityMember 2022-12-31 C008999 EMI 2022 Dec Storm Dist Ops - MSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Asset Suite/AIMM Repl - Supply Chaiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020 2021-12-31 C008999 Receipts & Sales, Other State Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 UPIC-DESOTO COUNTY-GETWELL RD-SHORTferc:ElectricUtilityMember 2022-12-31 C008999 FLIP North Coldwater 1L04 SCOPINGferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Terra Miss Nitrogen , OS , 2022-01-012022-12-31 C008999 Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205 2022-12-31 C008999 BELZONI, Distribution, Unattended 2022-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2022-12-31 C008999 GETWELL, Distribution, Unattended 2022-01-012022-12-31 C008999 ISES Acquisition Adjustment 2022-01-012022-12-31 C008999 NATCHEZ/INDUSTRIAL PARK, Distribution, Unattended 2022-12-31 C008999 Franchise - City, Local Tax, , 2022-12-31 C008999 System Energy Resources, Inc. , OS , 2022-01-012022-12-31 C008999 ScheduleElectricPropertyLeasedToOthersAbstract 2022-01-012022-12-31 C008999 NATCHEZ SWYD, Transmission, Unattended 2022-12-31 C008999 Executive Vice President and Chief Operating Officer of Entergy Corporation (1) 2022-01-012022-12-31 C008999 EDWARDS-JACKSON STREET-RELOCATE REGferc:ElectricUtilityMember 2022-12-31 C008999 ferc:PropertyTaxMember 2022-12-31 C008999 RS-39C Residential Service 2022-01-012022-12-31 C008999 STAR, Distribution, Unattended 2022-12-31 C008999 UPIC-Madison-Deweese Rd.-Westlake M 2022-01-012022-12-31 C008999 TERRY, Distribution, Unattended 2022-01-012022-12-31 C008999 PowerPlan Upgrade 2022ferc:ElectricUtilityMember 2022-12-31 C008999 Whitfield: add Ckt Sw, rpl T1 Diffferc:ElectricUtilityMember 2022-12-31 C008999 BEECH GROVE SS, Transmission, Unattended 2022-12-31 C008999 ferc:OtherAllocatedTaxMember 2022-12-31 C008999 C6ML300051: Flowers - Openwood 115k 2022-01-012022-12-31 C008999 UNDISTRIBUTED OVERHEADS: 2022-01-012022-12-31 C008999 MPSC Docket No. 2009-UN-388 - Attorney General Litigation 2022-01-012022-12-31 C008999 WOLF CREEK, MCADAMS 500 - [6960], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 UPIC-DESOTO COUNTY-GETWELL RD-SHORT 2022-01-012022-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Other Deductions (Account 4265)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 Entergy Mississippi, LLCferc:JulyMember 2022-01-012022-12-31 C008999 ferc:FederalTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember Mississippi Power & Light Co. 2021-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MCADAMS, PICKENS 230 - [6416], Wood H-Frame, 954 ACSR 2022-01-012022-12-31 C008999 Madison 115kV Second Xfmr T&D 2022-01-012022-12-31 C008999 INDIANOLA 115 SUB, Distribution, Unattended 2022-01-012022-12-31 C008999 0, 0 2022-01-012022-12-31 C008999 VICKSBURG/SOUTHEAST, Distribution, Unattended 2022-12-31 C008999 RALEIGH, Distribution, Unattended 2022-01-012022-12-31 C008999 SH21-013A Lewisburg School Scopingferc:ElectricUtilityMember 2022-12-31 C008999 State Income Tax, State Tax, , 2021-12-31 C008999 2022-CLINTON-TERRY SUB-7B04-JF073-H 2022-01-012022-12-31 C008999 Pwr Gen Remote Ops Projectferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Executive Vice President and Chief Financial Officer (1) 2022-01-012022-12-31 C008999 TYLERTOWN, Distribution, Unattended 2022-01-012022-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember Mississippi Power & Light Co. 2022-12-31 C008999 UFL-16 Urban Flood Lighting 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR4 - Rebuildferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Rankin 115kV Sub - Add Line Bayferc:ElectricUtilityMember 2022-12-31 C008999 ferc:OtherUseTaxMember 2022-01-012022-12-31 C008999 Total 230kV, , , 2022-01-012022-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2022-01-012022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-915 2022-01-012022-12-31 C008999 GRENADA/SOUTH, Transmission, Unattended 2022-01-012022-12-31 C008999 EML C Spire - Southern Routeferc:ElectricUtilityMember 2022-12-31 C008999 Gerald Andrus - Tinnin Rd 230kV CAP 2022-01-012022-12-31 C008999 HOY ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 Vice President and General Tax Counsel 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-N7, N8,ferc:ElectricUtilityMember 2022-12-31 C008999 Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021 2021-12-31 C008999 LUCKNEY, Distribution, Unattended 2022-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2022-12-31 C008999 ferc:PropertyTaxMember 2021-12-31 C008999 2021 Planning MD21-002A Rebuild R1 2022-01-012022-12-31 C008999 ELTON RD, Distribution, Unattended 2022-01-012022-12-31 C008999 Total 115kV, , , 2022-01-012022-12-31 C008999 VICKSBURG/SOUTHEAST, Distribution, Unattended 2022-01-012022-12-31 C008999 3.25% Series 2022-12-31 C008999 C6ML300042: Ray Braswell - Clinton 2022-01-012022-12-31 C008999 P2R Upgrade 2022-23 2022-01-012022-12-31 C008999 SWH-20 Gen. Space and Water Heating Serv. 2022-01-012022-12-31 C008999 ferc:ElectricPlantInServiceMember Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Energy Efficiency Rider Under-Recovery 2022-12-31 C008999 MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis 2022-01-012022-12-31 C008999 Sardis: E&D 1A22 & 24 Bkr Rpl 2022-01-012022-12-31 C008999 Video Management Solution Projectferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2021-12-31 C008999 2.55% Series 2022-12-31 C008999 ferc:ReactiveSupplyAndVoltageMember 2022-01-012022-12-31 C008999 NEW HEBRON, Distribution, Unattended 2022-12-31 C008999 MOON LAKE SS, Transmission, Unattended 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMemberferc:CurrentYearMember 2022-12-31 C008999 Liberty Development 2022-12-31 C008999 NATCHEZ, Distribution, Unattended 2022-01-012022-12-31 C008999 MCADAMS, ATTALA 230 - [6415], Steel Tower, 1272 ACSR 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMember Compliance Deductionferc:CurrentYearMember 2022-01-012022-12-31 C008999 Increases (Decreases) in Other Paid-In Capital 2022-01-012022-12-31 C008999 Vicksburg Openwd 115kVSub-AddTransfferc:ElectricUtilityMember 2022-12-31 C008999 FLY - Flora Transmission Laydown YD 2022-01-012022-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - New Build - UG 2022-01-012022-12-31 C008999 Other Reconciling Items - See footnote detail 2022-01-012022-12-31 C008999 ferc:Quarter1Member Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 Change in credit borrowings - net 2022-01-012022-12-31 C008999 RAY BRASWELL, LAKEOVER 500 - [7130], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 7%ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 TINNIN ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:RealEstateTaxMember 2021-12-31 C008999 Plum Point to Snowden Prk -115kv Lnferc:ElectricUtilityMember 2022-12-31 C008999 Hernando-Wooten Dr.-Winningham Estaferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 FONDREN/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 SPO EMISunflowerCoSolarBOTTransactnferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:Quarter3Member Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 Jackson Gas Light Company 2022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER18-1247 2022-01-012022-12-31 C008999 2021-SA20M014-Senatobia-1H05 2022-01-012022-12-31 C008999 Downtown Jackson - Replace 1500 KVAferc:ElectricUtilityMember 2022-12-31 C008999 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2022-01-012022-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2022-12-31 C008999 REVENUE - WEST POINT SUBDIVISION PH 2022-01-012022-12-31 C008999 Other 2021-01-012021-12-31 C008999 Stores Expense Undistributed (Account 163)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 ferc:SalesAndUseTaxMember 2022-01-012022-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2021-12-31 C008999 Non-Expense Accrued Labor 2022-01-012022-12-31 C008999 REX BROWN 230 SWYD, Transmission, Unattended 2022-01-012022-12-31 C008999 C6ML300039: Desoto - Walls 115kV CAferc:ElectricUtilityMember 2022-12-31 C008999 GALLMAN, Distribution, Unattended 2022-12-31 C008999 BRANDON, Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - FDR3 - Rebuildferc:ElectricUtilityMember 2022-12-31 C008999 C6ML300039: Desoto - Walls 115kV CA 2022-01-012022-12-31 C008999 2022 Data Analytics Platform - AWS 2022-01-012022-12-31 C008999 Other working capital 2021-01-012021-12-31 C008999 Other Debit or Cr. Items (Describe, details in footnote): 2022-01-012022-12-31 C008999 4.52% Series 2022-01-012022-12-31 C008999 FREEPORT, HORN LAKE 230 - [5942], Concrete Pole, 954 ACSR 2022-01-012022-12-31 C008999 Madison 115kV - Add 2nd Transformer 2022-01-012022-12-31 C008999 Other expenses incurred in connection wiht various filings before the FERC 2022-01-012022-12-31 C008999 ferc:UnemploymentTaxMember 2022-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER22-2202 2022-01-012022-12-31 C008999 MCKNIGHT, FRANKLIN 500 - [6980], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 FONDREN/JACKSON, Distribution, Unattended 2022-12-31 C008999 Corporate purchasing card rebates 2022-01-012022-12-31 C008999 Section 263A 2022-01-012022-12-31 C008999 Kimberly A. Fontan - Executive Vice President and Chief Financial Officer 2022-01-012022-12-31 C008999 Other 2021-12-31 C008999 Midcontinent ISO, Inc. , OS , 2022-01-012022-12-31 C008999 NORTHPARK, Distribution, Unattended 2022-12-31 C008999 Mississippi Power & Light Company 2022-12-31 C008999 ferc:SulfurDioxideMemberferc:NextTwelveMonthsMember 2022-01-012022-12-31 C008999 2022-MADISON-CHARITY CHURCH-RELOCAT 2022-01-012022-12-31 C008999 LULA, Distribution, Unattended 2022-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024 2022-01-012022-12-31 C008999 PAL-17 Private Area Lighting 2022-01-012022-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55ferc:ElectricUtilityMember 2022-12-31 C008999 ferc:Quarter4Member Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 Independence 2022-01-012022-12-31 C008999 CENTREVILLE, Distribution, Unattended 2022-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2022-01-012022-12-31 C008999 T&D - Snowden Park - New Build - UGferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Build Ckt. 8M10 to Feed Rex Lumberferc:ElectricUtilityMember 2022-12-31 C008999 T&D - Snowden Park - New Build - UGferc:ElectricUtilityMember 2022-12-31 C008999 FRANKLIN, RAY BRASWELL 500 - [6980], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 EMI 2022 Nov Storm Dist Ops - MS 2022-01-012022-12-31 C008999 FTO - Flora Transmission Officeferc:ElectricUtilityMember 2022-12-31 C008999 BAXTER WILSON SES SWYD, Transmission, Unattended 2022-01-012022-12-31 C008999 YAZOO CITY MUNICIPAL SS, Transmission, Unattended 2022-01-012022-12-31 C008999 Indianola - Tillatoba 230kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2022-01-012022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER22-2332 2022-01-012022-12-31 C008999 Indianola - Tillatoba 230kV CAP 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR2 Major Equferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Entergy Services, LLC, Income Tax, , 2022-12-31 C008999 EMI: Camlin Pilot Franklin EHVferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EML: 115kV|40kA|3000A Blue Breakerferc:ElectricUtilityMember 2022-12-31 C008999 CSD Workforce Management System 2022-01-012022-12-31 C008999 BAXTER WILSON, PERRYVILLE 500 - [5200], Steel Tower, 3070 AACSR 2022-01-012022-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 HENDERSON ROAD, Distribution, Unattended 2022-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2022-01-012022-12-31 C008999 FLORA, Distribution, Unattended 2022-12-31 C008999 Mississippi Power & Light Co. 2021-12-31 C008999 Gas Attala 2022-01-012022-12-31 C008999 Total 161kV, , , 2022-01-012022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER16-2199 2022-01-012022-12-31 C008999 EML: AC Reactor for Ray Braswellferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 HOLLANDALE, Distribution, Unattended 2022-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2021-12-31 C008999 Canton Rd:  Install Circuit Swi, Referc:ElectricUtilityMember 2022-12-31 C008999 UPIC-Hernando-Laughter Road S-Milleferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 NESBIT, Distribution, Unattended 2022-12-31 C008999 CO1 Additional Warehouse With Contferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Terry:  E&D 7B24 & 7B03 Bkr Rplferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GETWELL, Transmission, Unattended 2022-12-31 C008999 MCADAMS, INDIANOLA 230 - [6410], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 MONUMENT STREET/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 CO1 - Choctaw Emergency Generatorferc:ElectricUtilityMember 2022-12-31 C008999 HAZLEHURST, Distribution, Unattended 2022-12-31 C008999 MINTER CITY SS, Transmission, Unattended 2022-12-31 C008999 Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620 2022-12-31 C008999 JACKSON/WEST, Distribution, Unattended 2022-01-012022-12-31 C008999 MCADAMS EHV, Transmission, Unattended 2022-12-31 C008999 Hinds 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMember 2021-12-31 C008999 GM-Vicksburg SE Guild 5F02-IREG1, Iferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OperatingUtilityMember 2021-12-31 C008999 EMI: Camlin Pilot (Ray Braswell)ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Greenbrook to Snowden Park 115kv Ln 2022-01-012022-12-31 C008999 ScheduleHydroelectricGeneratingPlantStatisticsAbstract 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-R8 partferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2.85% Series 2022-01-012022-12-31 C008999 ferc:JanuaryMember 0 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMember 2022-01-012022-12-31 C008999 LAKE CASTLE, Distribution, Unattended 2022-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2022-12-31 C008999 Other Accounts (Specify, details in footnote): 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-200 2022-01-012022-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Inverness replace transformer J0135 2022-01-012022-12-31 C008999 LULA, Distribution, Unattended 2022-01-012022-12-31 C008999 VICKSBURG, Distribution, Unattended 2022-12-31 C008999 HORN LAKE, Distribution, Unattended 2022-12-31 C008999 ferc:GenerationSubstationMember 2022-12-31 C008999 Senior Vice President and Chief Accounting Officer (2) 2022-01-012022-12-31 C008999 GS-299 General Lighting and Power 2022-01-012022-12-31 C008999 GERALD ANDRUS, INDIANOLA 230 - [5580], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 Common equity distributions 2022-01-012022-12-31 C008999 COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022 2022-12-31 C008999 Other Accounts (Specify, provide details in footnote): 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR5 - Rebuild 2022-01-012022-12-31 C008999 Electric Deferred Fuel Under-Recovery 2022-12-31 C008999 Marks Add Circuit switchers & replaferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 See Footnote Detail 2022-01-012022-12-31 C008999 Land and Land Rights Under $250,000 2022-01-012022-12-31 C008999 CE Whitfield 115kV Add Breakersferc:ElectricUtilityMember 2022-12-31 C008999 GM-Guild 33-FJ05-Rebuild-Hickory Riferc:ElectricUtilityMember 2022-12-31 C008999 ferc:PenaltyTaxMember 2022-12-31 C008999 MIDNIGHT, Distribution, Unattended 2022-01-012022-12-31 C008999 Hollandale: E&D 3J22 & 3J02.ferc:ElectricUtilityMember 2022-12-31 C008999 T&D - Snowden Park - FDR3,4,5 - New 2022-01-012022-12-31 C008999 TWINKLETOWN, FREEPORT 230 - [5525], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2022-12-31 C008999 ferc:OtherAdValoremTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EMI 2022 Oct Storm Dist Ops - MSferc:ElectricUtilityMember 2022-12-31 C008999 ferc:FranchiseTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Build Pine Tree 230/12.47kV Subferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2022-01-012022-06-30 C008999 CO1 - Choctaw Emergency Generatorferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Greenville TCEPA - Arcola 115kV CAP 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR2 - New Buiferc:ElectricUtilityMember 2022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember EMI New Nuclear, LLC 2021-12-31 C008999 Purchases/Transfers:ferc:SulfurDioxideMember 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR2 - New Bui 2022-01-012022-12-31 C008999 Midcontinent Independent System Operator Inc 2022-01-012022-12-31 C008999 GREENVILLE/SOUTHEAST, Distribution, Unattended 2022-12-31 C008999 SIEM Optimizationferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 PSK405-1Y06-MALONE-MAJOR EQUIPMENTferc:ElectricUtilityMember 2022-12-31 C008999 HARPER, Transmission, Unattended 2022-01-012022-12-31 C008999 EDWARDS, Distribution, Unattended 2022-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAP 2022-01-012022-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2022-01-012022-12-31 C008999 Mobile device services 2022-01-012022-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2022-12-31 C008999 McAdams Relay Imprv. SPOF 2022-01-012022-12-31 C008999 Vicksburg N: Rpl 115KV Bus Diff Panferc:ElectricUtilityMember 2022-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2022-12-31 C008999 Greenville TCEPA - Arcola 115kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 ferc:OtherAdValoremTaxMember 2021-12-31 C008999 Greenville TCEPA - Arcola 115kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 OTHER GENERAL & INTANGIBLE PLANTferc:ElectricUtilityMember 2022-12-31 C008999 CHARLESTON, Distribution, Unattended 2022-12-31 C008999 GETWELL, Transmission, Unattended 2022-01-012022-12-31 C008999 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OtherFederalTaxMember 2022-01-012022-12-31 C008999 ferc:Quarter1Member 0 2022-01-012022-12-31 C008999 Section 263A 2021-12-31 C008999 UFL-16 Urban Flood Lighting 2022-01-012022-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5ferc:ElectricUtilityMember 2022-12-31 C008999 GLEN ALLAN, Distribution, Unattended 2022-01-012022-12-31 C008999 PORT GIBSON, Distribution, Unattended 2022-01-012022-12-31 C008999 SHELBY SS, Transmission, Unattended 2022-12-31 C008999 Brookhaven Upgrade Transformerferc:ElectricUtilityMember 2022-12-31 C008999 C6ML300069: Washington to Cranfieldferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMember Current Period Adjustmentferc:CurrentYearMember 2022-01-012022-12-31 C008999 RFL-16 Rural Flood Lighting 2022-01-012022-12-31 C008999 Gas Hinds 2022-01-012022-12-31 C008999 Madison 115kV - Add 2nd Transformerferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 BAXTER WILSON, GRAND GULF 500 - [5620], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 VICKSBURG/WEST, Distribution, Unattended 2022-12-31 C008999 2022 MISO Predictive Analytics 2022-01-012022-12-31 C008999 C6ML300043: Horn Lake - Greenbrookferc:ElectricUtilityMember 2022-12-31 C008999 CANTON ROAD/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 Indianola - Tillatoba 230kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - FDR4 - Rebuild 2022-01-012022-12-31 C008999 JONESTOWN SS, Transmission, Unattended 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMemberferc:TwoYearsMember 2022-01-012022-12-31 C008999 RANKIN, Transmission, Unattended 2022-01-012022-12-31 C008999 Case #10457 - Southaven - Holly Ridferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2022-01-012022-12-31 C008999 Other expenses incurred in connection with various filings before the MPSC 2022-01-012022-12-31 C008999 BRANDON, Distribution, Unattended 2022-01-012022-12-31 C008999 MOON LAKE, BATESVILLE 230 - [6300], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER21-262 2022-01-012022-12-31 C008999 ferc:OtherAdValoremTaxMember 2022-01-012022-12-31 C008999 Revolving Credit Facility 2022-01-012022-12-31 C008999 HORN LAKE, GETWELL 230 - [6186], Concrete Pole, 1272 ACSR 2022-01-012022-12-31 C008999 BROOKHAVEN-905 INDUSTRIAL PARK RD Nferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 C6ML300045: Canton - S. Canton 230k 2022-01-012022-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2021-12-31 C008999 LED-2 LED Street and Area  Lighting 2022-01-012022-12-31 C008999 MPSC Docket No. 2018-UN-205 - EML Formula Rate Plan 2022-12-31 C008999 BOZEMAN ROAD, Distribution, Unattended 2022-12-31 C008999 FLORENCE, Distribution, Unattended 2022-12-31 C008999 Pine Tree Substation T&D D-Scopingferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Privilege License, Other Taxes, , 2021-12-31 C008999 PI Visionferc:ElectricUtilityMember 2022-12-31 C008999 MISO Sch 2 Reactive 2022-01-012022-03-31 C008999 Mississippi Power & Light Co.ferc:CapitalContributionMember 2022-12-31 C008999 2020-12-31 C008999 Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39 2021-12-31 C008999 INVERNESS, Distribution, Unattended 2022-12-31 C008999 SARDIS, Distribution, Unattended 2022-01-012022-12-31 C008999 PWTHR IT Systemsferc:ElectricUtilityMember 2022-12-31 C008999 Lexington 115kv RplcXfmr-Scopingferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OtherTaxesAndFeesMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 JACKSON-VALLEY PARK II-PROVIAS CONS 2022-01-012022-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - FDR5 - New Buiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2022-01-012022-12-31 C008999 Regulatory Commission, Other Taxes, , 2022-01-012022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-2169 2022-01-012022-12-31 C008999 MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR5 - Rebuildferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 WYNNDALE, Distribution, Unattended 2022-12-31 C008999 3.85% Series 1 2022-12-31 C008999 EMI New Nuclear, LLC 2022-01-012022-12-31 C008999 Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022 2022-12-31 C008999 LAKEOVER, YANDELL RD 230 - [2335], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 Energy Efficiency Rider Under-Recovery 2021-12-31 C008999 Lakeover: Replace J9234 Breakerferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 VICKSBURG/EAST, Distribution, Unattended 2022-12-31 C008999 3% 2022-01-012022-12-31 C008999 TILLATOBA, BATESVILLE 230 - [5840], Concrete Pole, 1780 ACSR 2022-01-012022-12-31 C008999 Lakeover: Replace J9234 Breaker 2022-01-012022-12-31 C008999 Accrual Capital Proxy Code 2022-01-012022-12-31 C008999 Other working capital 2022-01-012022-12-31 C008999 WOLF CREEK, Transmission, Unattended 2022-12-31 C008999 CLINTON [MS], Distribution, Unattended 2022-01-012022-12-31 C008999 HAZLEHURST, Distribution, Unattended 2022-01-012022-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2022-12-31 C008999 EML C Spire - Southern Routeferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt 2021-01-012021-12-31 C008999 C6ML300080:  Flora - Little Yazoo (ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Long-Term Incentive Plan 2022-01-012022-12-31 C008999 VICKSBURG/NORTH, Distribution, Unattended 2022-01-012022-12-31 C008999 WESSON, Distribution, Unattended 2022-01-012022-12-31 C008999 Indianola RE-McAdms Rly Imprv.SPOFferc:ElectricUtilityMember 2022-12-31 C008999 2022 Customer NPS 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-2579 2022-01-012022-12-31 C008999 Accumulated Provisions for Property Insurance (Account 2281) 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1 2022-01-012022-12-31 C008999 2022-Southern Sky-Install Permanentferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CENTREVILLE, Distribution, Unattended 2022-01-012022-12-31 C008999 WALLS, Distribution, Unattended 2022-01-012022-12-31 C008999 EMI New Nuclear, LLC 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-215 2022-01-012022-12-31 C008999 Accrual Capital Proxy Codeferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CANTON/SOUTH, Distribution, Unattended 2022-01-012022-12-31 C008999 DELTA SWYD, Transmission, Unattended 2022-12-31 C008999 ferc:OtherStateTaxMember 2022-12-31 C008999 INVERNESS, Distribution, Unattended 2022-01-012022-12-31 C008999 Employment Litigation 2021-12-31 C008999 ScheduleCommonUtilityPlantAndExpensesAbstract 2022-01-012022-12-31 C008999 State Excise Tax, Excise Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MISO Various Various 2022-01-012022-12-31 C008999 4.9% Series 2022-12-31 C008999 ScheduleEnergyStorageOperationsLargePlantsAbstract 2022-01-012022-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2022-12-31 C008999 MCCOMB, Distribution, Unattended 2022-12-31 C008999 Midnight: rpl ABS J0348 & Steel Bus 2022-01-012022-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2022-12-31 C008999 JACKSON/NORTHEAST, Distribution, Unattended 2022-01-012022-12-31 C008999 Peter S. Norgeot, Jr. - Executive Vice President and Chief Operating Officer of Entergy Corporation 2022-01-012022-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 BOVINA, Distribution, Unattended 2022-12-31 C008999 TUNICA, Distribution, Unattended 2022-01-012022-12-31 C008999 Baird, Baird Rd, Mathew Miller Irri 2022-01-012022-12-31 C008999 HWY-2020-GM01-DF400-BOZEMAN RD UG 2ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GS-299 General Lighting and Power 2022-01-012022-12-31 C008999 JONESTOWN, Distribution, Unattended 2022-12-31 C008999 Baird, Baird Rd, Mathew Miller Irriferc:ElectricUtilityMember 2022-12-31 C008999 Gerald Andrus 2022-01-012022-12-31 C008999 EMI 2022 Dec Storm Dist Ops - MSferc:ElectricUtilityMember 2022-12-31 C008999 EMI 2022 Oct Storm Dist Ops - MSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Small Residential Generation , OS , 2022-01-012022-12-31 C008999 PICKENS, Transmission, Unattended 2022-12-31 C008999 2022-CLINTON-TERRY SUB-7B04-JF073-Hferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Hernando-Wooten Dr.-Winningham Estaferc:ElectricUtilityMember 2022-12-31 C008999 Plum Point to Snowden Prk -115kv Lnferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2021-GRENADA-ENID 2B01-MDOT BRIDGEferc:ElectricUtilityMember 2022-12-31 C008999 Long-Term Incentive Plan 2022-12-31 C008999 Sunflower, OS, 2022-01-012022-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2022-12-31 C008999 Franklin 115kV SPOF 2022-01-012022-12-31 C008999 Build Ckt. 8M10 to Feed Rex Lumberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Receipts & Sales, Other State Tax, , 2022-12-31 C008999 ferc:OtherUtilityMember Other (Specify) 2022-01-012022-12-31 C008999 2022 Woodrow Wilson Relocationferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:DirectPayrollDistributionMember Miscellaneous Deferred Debits (Account 186) 2022-01-012022-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2021-12-31 C008999 MONUMENT STREET/JACKSON, Distribution, Unattended 2022-12-31 C008999 STAR, Distribution, Unattended 2022-01-012022-12-31 C008999 BOWLING GREEN SS, Transmission, Unattended 2022-12-31 C008999 ferc:OtherFederalTaxMember 2022-12-31 C008999 EML Public EV Charging Pilot 2022-01-012022-12-31 C008999 2021-GRENADA-ENID 2B01-MDOT BRIDGEferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Deferred Electric Storm Restoration Costs 2021-12-31 C008999 GRENADA/SOUTH, Distribution, Unattended 2022-12-31 C008999 Pelahatchie - Rankin 115kV CAP 2022-01-012022-12-31 C008999 Other 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,2 - Rebui 2022-01-012022-12-31 C008999 MEADVILLE, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300059: Liberty - Gillsburg 115ferc:ElectricUtilityMember 2022-12-31 C008999 MOON LAKE SS, Transmission, Unattended 2022-12-31 C008999 ferc:OtherTaxMember 2021-12-31 C008999 ferc:SeveranceTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Qualified Pension funded status 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR3 - Rebuild 2022-01-012022-12-31 C008999 C6ML300040: S. Natchez - Natchez Inferc:ElectricUtilityMember 2022-12-31 C008999 2021-GRENADA-ENID 2B01-MDOT BRIDGE 2022-01-012022-12-31 C008999 Add Ckt. 9A06  to Poleline for Secoferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Crenshaw: Add Circuit Switcherferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MORTON, Distribution, Unattended 2022-12-31 C008999 Lexington 115kv RplcXfmr-Scoping 2022-01-012022-12-31 C008999 Roderick K. 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Canton 230kferc:ElectricUtilityMember 2022-12-31 C008999 Whitfield: add Ckt Sw, rpl T1 Diffferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SH21-011V NRT - Multiphase Addition 2022-01-012022-12-31 C008999 Accrual Capital Proxy Codeferc:ElectricUtilityMember 2022-12-31 C008999 FLIP North Coldwater 1L04 SCOPING 2022-01-012022-12-31 C008999 Distribution Resiliency Planferc:ElectricUtilityMember 2022-12-31 C008999 VICKSBURG/SOUTH, Distribution, Unattended 2022-12-31 C008999 Franklin 115kV SPOFferc:ElectricUtilityMember 2022-12-31 C008999 GM-Vicksburg SE Guild 5F02-IREG1, I 2022-01-012022-12-31 C008999 CANTON/SOUTH, Distribution, Unattended 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022 2022-01-012022-12-31 C008999 FAYETTE 2022-01-012022-12-31 C008999 Baxter Wilson Oil 2022-01-012022-12-31 C008999 ATTALA, Transmission, Unattended 2022-01-012022-12-31 C008999 Mississippi Power & Light Company 2022-01-012022-12-31 C008999 C6ML300051: Flowers - Openwood 115kferc:ElectricUtilityMember 2022-12-31 C008999 Entergy Mississippi, LLCferc:OctoberMember 2022-01-012022-12-31 C008999 Executive Vice President and Chief Financial Officer (2) 2022-01-012022-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2021-12-31 C008999 ferc:Quarter2Member 0 2022-01-012022-12-31 C008999 Choctaw 2022-12-31 C008999 COMO, Distribution, Unattended 2022-12-31 C008999 SNOWDEN PARK DIST. 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Natchez - Natchez Inferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 RANKIN, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300045: Canton - S. Canton 230kferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GEORGETOWN [MS], Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 C6ML300059: Liberty - Gillsburg 115ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MOORHEAD, Distribution, Unattended 2022-12-31 C008999 HLF-7 High Load Factor 2022-01-012022-12-31 C008999 MPSC Docket No. 2010-AD-2 - MS EE Comprehensive Portfolio Program 2022-01-012022-12-31 C008999 ferc:DistributionSubstationMember 2022-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2021-12-31 C008999 Miss. Signage Rebranding Costs 2022-01-012022-12-31 C008999 AD21M004 - FOCUS - 1D02 - K1511ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SW-Facilities Ratings WS-NERC Rep 2022-01-012022-12-31 C008999 Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022 2022-01-012022-12-31 C008999 Lakeover-Hinds 230kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Changes in money pool receivable - net 2021-01-012021-12-31 C008999 C6ML300042: Ray Braswell - Clintonferc:ElectricUtilityMember 2022-12-31 C008999 GRENADA, Distribution, Unattended 2022-12-31 C008999 B(4), Smart Electric Power Alliance 2022-01-012022-12-31 C008999 Hollandale: E&D 3J22 & 3J02. 2022-01-012022-12-31 C008999 Privilege License, Other Taxes, , 2022-01-012022-12-31 C008999 Southaven-Getwell Road-M&R Buildersferc:ElectricUtilityMember 2022-12-31 C008999 E. Vicksburg-E. Vicksburg 115kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb) 2022-01-012022-12-31 C008999 BOZEMAN ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 Build Pine Tree 230/12.47kV Sub 2022-01-012022-12-31 C008999 State Use Tax, Sales And Use Tax, , 2022-01-012022-12-31 C008999 EPG GridUnityferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 PGen Smart Proceduresferc:ElectricUtilityMember 2022-12-31 C008999 B-34 Intermediate General Service 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-827 2022-01-012022-12-31 C008999 ferc:ElectricUtilityMember 2021-12-31 C008999 ferc:AdValoremTaxMember 2022-12-31 C008999 Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620 2022-01-012022-12-31 C008999 DSL-16 Directional Security  Lighting 2022-01-012022-12-31 C008999 MPSC Docket No. 2008-UN-388 - EML Formula Rate Plan 2022-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1449 2022-01-012022-12-31 C008999 See Footnote Detail 2022-01-012022-12-31 C008999 2021-SA20M014-Senatobia-1H05ferc:ElectricUtilityMember 2022-12-31 C008999 Add Ckt. 9A06  to Poleline for Secoferc:ElectricUtilityMember 2022-12-31 C008999 GETWELL, BYHALA 230 - [2341], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 GREENVILLE/INDUSTRIAL, Distribution, Unattended 2022-12-31 C008999 RS-39W Residential Water Heating Service 2022-01-012022-12-31 C008999 OTHER DISTRIBUTION LINES PLANT 2022-01-012022-12-31 C008999 JACKSON/TREATMENT PLANT, Distribution, Unattended 2022-01-012022-12-31 C008999 See Footnote Detail 2022-01-012022-12-31 C008999 EMI Sunflower County SolarOversight 2022-01-012022-12-31 C008999 ScheduleNuclearFuelMaterialsAbstract 2022-01-012022-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 2022-01-012022-12-31 C008999 ferc:PayrollTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 4%ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CRENSHAW, Distribution, Unattended 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2022-12-31 C008999 SE21-004V EMI Sycamore Wakefield ROferc:ElectricUtilityMember 2022-12-31 C008999 YANDELL RD, Distribution, Unattended 2022-12-31 C008999 FICA, Federal Tax, , 2022-01-012022-12-31 C008999 SH21-011V NRT - Multiphase Additionferc:ElectricUtilityMember 2022-12-31 C008999 GM - Guild 33 - FA06 - Rebuild - Clferc:ElectricUtilityMember 2022-12-31 C008999 Deferred rebate 2021-12-31 C008999 OTHER TRANSMISSION LINES PLANTferc:ElectricUtilityMember 2022-12-31 C008999 ferc:LandAndRightsMember Land and Land Rights Under $250,000 2022-01-012022-12-31 C008999 COUNTRY CLUB/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 GALLATIN STREET/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 Entergy Power & Light Company 2022-01-012022-12-31 C008999 PWTHR IT Systems 2022-01-012022-12-31 C008999 EML Public EV Charging Pilotferc:ElectricUtilityMember 2022-12-31 C008999 SH21-012V Lewisburg School Projectferc:ElectricUtilityMember 2022-12-31 C008999 JOHNS MANVILLE, Distribution, Unattended 2022-12-31 C008999 LAKEOVER EHV, Transmission, Unattended 2022-12-31 C008999 FERNWOOD, Distribution, Unattended 2022-01-012022-12-31 C008999 GS-299 MS Gen. Lghtg & Pwr Muni. Service 2022-01-012022-12-31 C008999 Mannsdale 230kV Substation 2022-01-012022-12-31 C008999 GS-299 General Lighting and Power 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,3 - Rebuiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2.85% Series 2022-12-31 C008999 2021 Planning MD21-002A Rebuild R1ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:PropertyTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MPSC Docket No. 2009-UN-388 - Attorney General Litigation 2022-12-31 C008999 YAZOO CITY SS, Distribution, Unattended 2022-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 FLY - Flora Transmission Laydown YDferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 State Excise Tax, Excise Tax, , 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,3 - UG Ne 2022-01-012022-12-31 C008999 Vegetation Management Rider MPSC Docket No. 2018-UN-205 2021-12-31 C008999 Allowances Usedferc:SulfurDioxideMember 2022-01-012022-12-31 C008999 ferc:SchedulingSystemControlAndDispatchMember 2022-01-012022-12-31 C008999 SOUTH JACKSON, RANKIN 230 - [7350], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 WINONA, Distribution, Unattended 2022-01-012022-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2022-01-012022-12-31 C008999 2022-01-012022-09-30 C008999 ferc:NitrogenOxideMemberferc:CurrentYearMember 2021-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2021-12-31 C008999 2021 - SENATOBIA - LULA - 1K01 - Q1ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2022-Grenada-Grenada-2L02-Milwaukeeferc:ElectricUtilityMember 2022-12-31 C008999 ferc:FranchiseTaxMember 2022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER22-1602 2022-01-012022-12-31 C008999 EMI 2022 Oct Storm Dist Ops - MS 2022-01-012022-12-31 C008999 EML: 115-13.8kV | 20MVA LTCferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 3.85% Series 1 2022-01-012022-12-31 C008999 ferc:StateTaxMember 2022-12-31 C008999 ferc:OtherPropertyTaxMember 2021-12-31 C008999 Other 2022-01-012022-12-31 C008999 Income Taxes 2021-12-31 C008999 OTHER PRODUCTION PLANT 2022-01-012022-12-31 C008999 BYRAM, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300068: Natchez to Washington S 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR4 - New Buiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GM-Guild 33-FJ05-Rebuild-Hickory Riferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Rankin Industrial - OH to UG Highwaferc:ElectricUtilityMember 2022-12-31 C008999 IBM MRO IO Entergy Interfaceferc:ElectricUtilityMember 2022-12-31 C008999 MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan 2022-12-31 C008999 WOODVILLE [MS], Distribution, Unattended 2022-01-012022-12-31 C008999 HWY-2020-GM01-DF400-BOZEMAN RD UG 2 2022-01-012022-12-31 C008999 HERNANDO, Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-N7, N8,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2022-01-012022-12-31 C008999 0ferc:JulyMember 2022-01-012022-12-31 C008999 RAYMOND, Distribution, Unattended 2022-01-012022-12-31 C008999 ATTALA, Transmission, Unattended 2022-12-31 C008999 ferc:OtherUseTaxMember 2021-12-31 C008999 TINNIN RD, GERALD ANDRUS 230 - [52304], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 CLINTON INDUSTRIAL, Distribution, Unattended 2022-12-31 C008999 Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1, Docket No. ER13-948 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMemberferc:AfterThreeYearsMember 2022-12-31 C008999 UPIC - Hernando-Robertson Gin Rd.-Mferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2022-12-31 C008999 SW2 - EDE-Bill Syst Contr Repo Inteferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 The Light, Heat and Water Company of Jackson, Mississippi 2022-01-012022-12-31 C008999 B(4), SERC 2022-01-012022-12-31 C008999 ferc:Quarter2Member Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 2021 - SENATOBIA - LULA - 1K01 - Q1ferc:ElectricUtilityMember 2022-12-31 C008999 GETWELL, TWINKLETOWN 230 - [5007], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 3%ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 C6ML300043: Horn Lake - Greenbrookferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-12-31 C008999 ferc:FuelTaxMember 2022-12-31 C008999 TINNIN ROAD, Distribution, Unattended 2022-12-31 C008999 LAKEOVER, LUCKNEY 230 - [2311], Steel Tower, 1272 ACSR 2022-01-012022-12-31 C008999 HWY-2020-GM01-DF400-BOZEMAN RD UG 2ferc:ElectricUtilityMember 2022-12-31 C008999 Changes in money pool receivable - net 2022-01-012022-12-31 C008999 IPS-26 Irrigation Pumping Power 2022-01-012022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER21-1997 2022-01-012022-12-31 C008999 RAY BRASWELL, S JACKSON 230 - [7370], Concrete Pole, 1272 ACSR 2022-01-012022-12-31 C008999 MADISON, Distribution, Unattended 2022-12-31 C008999 2022 Customer NPSferc:ElectricUtilityMember 2022-12-31 C008999 SHELBY, Distribution, Unattended 2022-12-31 C008999 EMI: Camlin Pilot (Freeport)ferc:ElectricUtilityMember 2022-12-31 C008999 TUNICA, TWINKLETOWN 230 - [5525], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 EMI New Nuclear, LLCferc:SubsidiaryCompanySubheadingMember 2022-01-012022-12-31 C008999 GLEN ALLAN, Distribution, Unattended 2022-12-31 C008999 Midnight: rpl ABS J0348 & Steel Busferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Hernando-Getwell Rd.-Short Fork Devferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Mississippi Power & Light Co.ferc:SubsidiaryCompanySubheadingMember 2022-01-012022-12-31 C008999 MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb)ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Marks Add Circuit switchers & replaferc:ElectricUtilityMember 2022-12-31 C008999 Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 Amort July 2021-June 2022 2022-01-012022-12-31 C008999 2022 Dist Capital Tools EMLferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2022-01-012022-12-31 C008999 HIGHWAY - GRANTS FERRY PARKWAY RELOferc:ElectricUtilityMember 2022-12-31 C008999 Video Management Solution Projectferc:ElectricUtilityMember 2022-12-31 C008999 Miss. Signage Rebranding Costsferc:ElectricUtilityMember 2022-12-31 C008999 ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 A(3) B(4), Advanced meters 2022-01-012022-12-31 C008999 2022-Southern Sky-Install Permanentferc:ElectricUtilityMember 2022-12-31 C008999 FLOWOOD, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:Quarter3Member 0 2022-01-012022-12-31 C008999 4.9% Series 2022-01-012022-12-31 C008999 BYHALIA, Distribution, Unattended 2022-12-31 C008999 TUNICA 230/115 SUB, Transmission, Unattended 2022-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2022-12-31 C008999 Civil, Political, and Related Expenses (Account 4264)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract 2022-01-012022-12-31 C008999 ferc:ExciseTaxMember 2022-01-012022-12-31 C008999 Relocate Facilities W Capitol St 2022-01-012022-12-31 C008999 ALGS-10 Alternate Large General Service 2022-01-012022-12-31 C008999 PSK405-1Y06-MALONE-MAJOR EQUIPMENTferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EMI 2022 Nov Storm Dist Ops - MSferc:ElectricUtilityMember 2022-12-31 C008999 Non Income Tax, Miscellaneous Other Tax, , 2022-01-012022-12-31 C008999 C6ML300057: East Jackson - Fannin Rferc:ElectricUtilityMember 2022-12-31 C008999 Other Accounts (Specify, details in footnote):ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Rotating Load Shed Software Impferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 JACKSON/SOUTHWEST, Distribution, Unattended 2022-01-012022-12-31 C008999 MARKS, Distribution, Unattended 2022-12-31 C008999 Asset Suite/AIMM Repl - Supply Chaiferc:ElectricUtilityMember 2022-12-31 C008999 KINGSWOOD/JACKSON, Distribution, Unattended 2022-12-31 C008999 Receipts & Sales, Other State Tax, , 2021-12-31 C008999 GM-Vicksburg SE Guild 5F03-R8 part 2022-01-012022-12-31 C008999 CHOCTAW, FRENCH CAMP 500 - [5014], Steel Pole, 954 ACSR 2022-01-012022-12-31 C008999 SOUTH CANTON, RAGSDALE 230 LN 2 - [5271], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 CHARLESTON, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300040: S. Natchez - Natchez In 2022-01-012022-12-31 C008999 Asset Retirement Obligation - Fossil 2021-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2021-12-31 C008999 Entergy Services, LLC, Income Tax, , 2022-01-012022-12-31 C008999 2020 - Focus - FC20M048 - Madison -ferc:ElectricUtilityMember 2022-12-31 C008999 Build Ckt. 8M10 for Dedicated Feed 2022-01-012022-12-31 C008999 Sunflower Betterment Spend Approachferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 LIBERTY, Distribution, Unattended 2022-01-012022-12-31 C008999 ALGS-10 / Other 2022-01-012022-12-31 C008999 NEW HEBRON, Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwoodferc:ElectricUtilityMember 2022-12-31 C008999 Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132 2021-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2022-01-012022-12-31 C008999 ferc:MarchMember 0 2022-01-012022-12-31 C008999 GERALD ANDRUS SES SWYD, Transmission, Unattended 2022-12-31 C008999 Build Pine Tree 230/12.47kV Subferc:ElectricUtilityMember 2022-12-31 C008999 Build Ckt. 8M10 to Feed Rex Lumber 2022-01-012022-12-31 C008999 ferc:IncomeTaxMember 2022-12-31 C008999 Senior Vice President and Chief Accounting Officer (1) 2022-01-012022-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2022-01-012022-12-31 C008999 Liberty Development 2022-01-012022-12-31 C008999 Digital LIHEAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OtherTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 NORTHSIDE DRIVE/JACKSON, Distribution, Unattended 2022-12-31 C008999 SARDIS, Distribution, Unattended 2022-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2022-01-012022-12-31 C008999 2021-SA20M014-Senatobia-1H05ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1777 2022-01-012022-12-31 C008999 FAYETTE, Distribution, Unattended 2022-01-012022-12-31 C008999 DA Settings Management 2022-01-012022-12-31 C008999 SPO EMISunflowerCoSolarBOTTransactn 2022-01-012022-12-31 C008999 Privilege License, Other Taxes, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 RULEVILLE, Distribution, Unattended 2022-12-31 C008999 PSK405-1Y06-MALONE-MAJOR EQUIPMENT 2022-01-012022-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwoodferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Rainbow Energy Marketing Corp, OS, 2022-01-012022-12-31 C008999 RAY BRASWELL, SOUTH JACKSON 230 - [7375], Steel Tower, 1272 ACSR 2022-01-012022-12-31 C008999 GM-Guild 33-FA06-Rebuild-Cleary Rdferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:MiscellaneousOtherTaxMember 2022-01-012022-12-31 C008999 EMPLOYMENT TAXES (Account 40811)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 UPIC-HORN LAKE-WILLOW OAK DR-WILLOW 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,3 - Rebui 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR5 - Rebuildferc:ElectricUtilityMember 2022-12-31 C008999 4.52% Series 2022-12-31 C008999 Corporate Franchise Tax-MS, Franchise Tax, , 2022-01-012022-12-31 C008999 PICKENS, Transmission, Unattended 2022-01-012022-12-31 C008999 Income Taxes 2021-12-31 C008999 Southaven-Getwell Road-M&R Builders 2022-01-012022-12-31 C008999 ferc:OtherLicenseAndFeesTaxMember 2022-01-012022-12-31 C008999 Attala 2022-01-012022-12-31 C008999 ELTON RD, Distribution, Unattended 2022-12-31 C008999 C6ML300060 Liberty - Gloster 115kV 2022-01-012022-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-Inferc:ElectricUtilityMember 2022-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2021-12-31 C008999 B(1), EPRI 2 2022-01-012022-12-31 C008999 OTHER TRANSMISSION & DISTRIBUTION SUBSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 WHITFIELD, Distribution, Unattended 2022-12-31 C008999 ferc:NitrogenOxideMemberferc:TwoYearsMember 2022-01-012022-12-31 C008999 Increases (Decreases) Due to Miscellaneous Paid-In Capital 2022-01-012022-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2022-01-012022-12-31 C008999 LARSON ST/JACKSON, Distribution, Unattended 2022-12-31 C008999 Bowling Green - Durant 115kV CAP 2022-01-012022-12-31 C008999 Jackson Gas Light Company 2022-01-012022-12-31 C008999 QF-18 2022-01-012022-12-31 C008999 ferc:MiscellaneousOtherTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ATTALA, Distribution, Unattended 2022-12-31 C008999 BAXTER WILSON SES SWYD, Transmission, Unattended 2022-12-31 C008999 WEBB, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMember Compliance Deduction 2022-01-012022-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2022-01-012022-12-31 C008999 MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis 2022-12-31 C008999 ferc:MayMember 0 2022-01-012022-12-31 C008999 Electric Deferred Fuel Under-Recovery 2022-01-012022-12-31 C008999 OTHER DISTRIBUTION LINES PLANTferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMemberferc:TwoYearsMember 2022-12-31 C008999 McAdams Relay Imprv. SPOFferc:ElectricUtilityMember 2022-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2022-01-012022-12-31 C008999 Hernando-Getwell Rd.-Short Fork Devferc:ElectricUtilityMember 2022-12-31 C008999 T&D - Snowden Park - FDR4 - New Buiferc:ElectricUtilityMember 2022-12-31 C008999 Electric Deferred Fuel Under-Recovery 2021-12-31 C008999 Mississippi ITCferc:OtherUtilityOrNonutilityMember 2021-12-31 C008999 TUNICA 230/115 SUB, Transmission, Unattended 2022-01-012022-12-31 C008999 Sardis: E&D 1A22 & 24 Bkr Rplferc:ElectricUtilityMember 2022-12-31 C008999 GREENWOOD, Distribution, Unattended 2022-12-31 C008999 Midnight: rpl ABS J0348 & Steel Busferc:ElectricUtilityMember 2022-12-31 C008999 IBM MRO IO Entergy Interface 2022-01-012022-12-31 C008999 GETWELL, Distribution, Unattended 2022-12-31 C008999 Entergy Services, LLC, Income Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EML C Spire - Southern Route 2022-01-012022-12-31 C008999 ferc:OtherTaxMember 2022-12-31 C008999 RXC Lake Hico Closure Planferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CO1 - Choctaw Emergency Generator 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER16-227 2022-01-012022-12-31 C008999 ferc:TransmissionSubstationMember 2022-12-31 C008999 AMI - DMS/OMS - Software - Rel 4-5 2022-01-012022-12-31 C008999 ferc:OtherAllocatedTaxMember 2022-01-012022-12-31 C008999 B(2), Edison Electric Institute 2022-01-012022-12-31 C008999 ENID, Distribution, Unattended 2022-01-012022-12-31 C008999 LUCKNEY, Distribution, Unattended 2022-01-012022-12-31 C008999 EML: 115-13.8 | 20MVA (Marvell)ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 NATCHEZ SWYD, Transmission, Unattended 2022-01-012022-12-31 C008999 ferc:ExciseTaxMember 2022-12-31 C008999 JACKSON-VALLEY PARK II-PROVIAS CONSferc:ElectricUtilityMember 2022-12-31 C008999 Greenbrook to Snowden Park 115kv Lnferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ATTALA PLANT, Transmission, Unattended 2022-12-31 C008999 CLEVELAND/SOUTH, Distribution, Unattended 2022-01-012022-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MIAMI STREET/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 MORTON, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2022-12-31 C008999 ferc:DecemberMember 0 2022-01-012022-12-31 C008999 Asset Retirement Obligation - Fossil 2022-01-012022-12-31 C008999 SIEM Optimizationferc:ElectricUtilityMember 2022-12-31 C008999 Federal Excise Tax, Federal Tax, , 2022-12-31 C008999 ferc:SalesAndUseTaxMember 2022-12-31 C008999 HORN LAKE, ALLEN S 161 - [5960], Steel Pole, 954 ACSS 2022-01-012022-12-31 C008999 SPO EML SunflowerTaxEquityPartneshp 2022-01-012022-12-31 C008999 JOHNS MANVILLE, Distribution, Unattended 2022-01-012022-12-31 C008999 GM - Guild 33 - FJ05 - Rebuild - Hiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 WEBB, Distribution, Unattended 2022-12-31 C008999 DREW [MS], Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-R8 partferc:ElectricUtilityMember 2022-12-31 C008999 ferc:MayMember Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR3 - Rebuildferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Distribution Resiliency Plan 2022-01-012022-12-31 C008999 PGen Smart Proceduresferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 3.25% Series 2022-01-012022-12-31 C008999 HN1 - Hinds LTSA Capitalferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CLARKSDALE, Distribution, Unattended 2022-12-31 C008999 CE Whitfield 115kV Add Breakersferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ROBINSONVILLE, Distribution, Unattended 2022-01-012022-12-31 C008999 JACKSON/SOUTH, Transmission, Unattended 2022-12-31 C008999 ferc:OtherUtilityOrNonutilityMember 0 2022-01-012022-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 - Amort pd Aug 2022 thru June 2023 2022-01-012022-12-31 C008999 Mississippi ITCferc:OtherUtilityOrNonutilityMember 2022-12-31 C008999 RS-39C Residential Service 2022-01-012022-12-31 C008999 ferc:OtherProductionPlantMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Baird, Baird Rd, Mathew Miller Irriferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Dist.Transformers Outage Prediction 2022-01-012022-12-31 C008999 Build Ckt. 8M10 for Dedicated Feedferc:ElectricUtilityMember 2022-12-31 C008999 2022-Southern Sky-Install Permanent 2022-01-012022-12-31 C008999 UPIC-HORN LAKE-WILLOW OAK DR-WILLOWferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Asset Retirement Obligation - Coal 2022-12-31 C008999 BOLTON, Distribution, Unattended 2022-12-31 C008999 CHOCTAW, Transmission, Unattended 2022-12-31 C008999 DURANT, Distribution, Unattended 2022-12-31 C008999 KOSCIUSKO, Distribution, Unattended 2022-01-012022-12-31 C008999 2020 - SOUTHAVEN - PLUM POINT - CHUferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SW-Network Access Control Authentic 2022-01-012022-12-31 C008999 3.5% Series 1 2022-12-31 C008999 GS-299 MS Gen. Lghtg & Pwr Muni. Service 2022-01-012022-12-31 C008999 2022-CLINTON-TERRY SUB-7B04-JF073-Hferc:ElectricUtilityMember 2022-12-31 C008999 Mark-to-Market 2022-01-012022-12-31 C008999 State Income Tax, State Tax, , 2022-12-31 C008999 MEDICAL CENTER/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 ROBINSONVILLE, Distribution, Unattended 2022-12-31 C008999 Pelahatchie - Rankin 115kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 See footnote for schedule details, 2022-01-012022-12-31 C008999 Clarksdale replace transformer J292ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Non-Qualified Pension funded status 2021-12-31 C008999 MISO Sch 1 Sched/Sys Ctrl/Disp 2022-01-012022-06-30 C008999 CO1 LTSA Capitalization 2022-01-012022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember Mississippi Power & Light Co. 2022-01-012022-12-31 C008999 ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract 2022-01-012022-12-31 C008999 ferc:UnemploymentTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Other Property Under $250,000ferc:OtherPropertyMember 2022-12-31 C008999 C6ML300058: E. Jackson - S. Jacksonferc:ElectricUtilityMember 2022-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2022-12-31 C008999 Whitfield: add Ckt Sw, rpl T1 Diff 2022-01-012022-12-31 C008999 ferc:OtherFederalTaxMember 2021-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER20-1472 2022-01-012022-12-31 C008999 ferc:FederalInsuranceTaxMember 2022-12-31 C008999 WOLF CREEK, FRENCH CAMP 500 - [6960], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 JACKSON - E. CAPITOL ST. - CITY OFferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 4% 2022-01-012022-12-31 C008999 ferc:AdValoremTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021 2022-12-31 C008999 ferc:LocalTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SCHLATER, Distribution, Unattended 2022-01-012022-12-31 C008999 Other Deductions (Account 4265) 2022-01-012022-12-31 C008999 PowerPlan Upgrade 2022ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,3 - UG Neferc:ElectricUtilityMember 2022-12-31 C008999 GREENVILLE, Distribution, Unattended 2022-01-012022-12-31 C008999 NATCHEZ, Distribution, Unattended 2022-12-31 C008999 Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 Amort July 2021-June 2022 2021-12-31 C008999 RAY BRASWEL, REX BROWN 230 - [7100], Wood H-Frame, 1272 ACSS 2022-01-012022-12-31 C008999 HERNANDO, Distribution, Unattended 2022-12-31 C008999 ferc:IncomeTaxMember 2021-12-31 C008999 ferc:PropertyTaxMember 2022-01-012022-12-31 C008999 C6ML300069: Washington to Cranfield 2022-01-012022-12-31 C008999 Midcontinent ISO, Inc., OS, 2022-01-012022-12-31 C008999 ferc:SeveranceTaxMember 2022-12-31 C008999 Derivative Instruments and Hedging Activities 2022-12-31 C008999 T&D - Snowden Park - FDR1,3 - Rebuiferc:ElectricUtilityMember 2022-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2022-01-012022-12-31 C008999 Miscellaneous Current and Accrued Assets (Account 174) 2022-01-012022-12-31 C008999 RAY BRASWELL, NORREL 230 - [2340], Steel Tower, 1272 ACSR 2022-01-012022-12-31 C008999 C6ML300060 Liberty - Gloster 115kVferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OperatingUtilityMember 2022-01-012022-12-31 C008999 ELLIOTT, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300002: Horn Lake - DeSoto 115kferc:ElectricUtilityMember 2022-12-31 C008999 COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022 2021-12-31 C008999 Mark-to-Market 2022-12-31 C008999 MISO Financial Transmission Rights Mark-to-Market 2022-12-31 C008999 GLP-17 Gen. Lghtg. & Pwr Redist. & Res. 2022-01-012022-12-31 C008999 DSL-16 Directional Security  Lighting 2022-01-012022-12-31 C008999 Franklin-GGNS 500Kv Phase Swaferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MPSC Docket No. 2008-UN-388 - EML Formula Rate Plan 2022-01-012022-12-31 C008999 GM-Guild 33-GK01-Rebuild-Brookwood 2022-01-012022-12-31 C008999 9C01- State Line Exploration- 3-phaferc:ElectricUtilityMember 2022-12-31 C008999 PI Vision 2022-01-012022-12-31 C008999 Gerald Andrus 2022-12-31 C008999 LED-2 LED Street and Area  Lighting 2022-01-012022-12-31 C008999 WESSON, Distribution, Unattended 2022-12-31 C008999 C6ML300060 Liberty - Gloster 115kVferc:ElectricUtilityMember 2022-12-31 C008999 PAL-17 Private Area Lighting 2022-01-012022-12-31 C008999 RS-39W Residential Water Heating Service 2022-01-012022-12-31 C008999 Other Property Under $250,000 2022-01-012022-12-31 C008999 GM - Guild 33 - FJ05 - Rebuild - Hi 2022-01-012022-12-31 C008999 Baxter Wilson 2022-12-31 C008999 GM-Vicksburg SE Guild 5F02-IA1; 5F0ferc:ElectricUtilityMember 2022-12-31 C008999 RANKIN INDTRL./JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 Marks Add Circuit switchers & repla 2022-01-012022-12-31 C008999 HOLLANDALE, Distribution, Unattended 2022-01-012022-12-31 C008999 2022 Dist Capital Tools EML 2022-01-012022-12-31 C008999 SNOWDEN PARK DIST. ROWferc:ElectricUtilityMember 2022-12-31 C008999 EPG GridUnityferc:ElectricUtilityMember 2022-12-31 C008999 Rotating Load Shed Software Impferc:ElectricUtilityMember 2022-12-31 C008999 ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract 2022-01-012022-12-31 C008999 B(4), Environmental Research 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMember Current Period Adjustment 2022-01-012022-12-31 C008999 LED-2 LED Street and Area  Lighting 2022-01-012022-12-31 C008999 ferc:FederalInsuranceTaxMember 2021-12-31 C008999 ferc:OtherFederalTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2022-12-31 C008999 EMI: Camlin Pilot Franklin EHV 2022-01-012022-12-31 C008999 Accumulated Provisions for Property Insurance (Account 2281)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 2020 Planning CL20-005V Rep A1, RREferc:ElectricUtilityMember 2022-12-31 C008999 , , 2022-01-012022-12-31 C008999 PLUM POINT, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMember 2022-01-012022-12-31 C008999 ferc:OtherPropertyTaxMember 2022-12-31 C008999 FLORENCE, Distribution, Unattended 2022-01-012022-12-31 C008999 Mannsdale T&D D-Scoping 2022-01-012022-12-31 C008999 BROOKHAVEN/SOUTH, Distribution, Unattended 2022-01-012022-12-31 C008999 PLUM POINT, Distribution, Unattended 2022-12-31 C008999 ferc:SeveranceTaxMember 2021-12-31 C008999 UPIC-Southaven-Rasco Rd-Johnny Coleferc:ElectricUtilityMember 2022-12-31 C008999 WALLS, Distribution, Unattended 2022-12-31 C008999 BYRAM, Distribution, Unattended 2022-12-31 C008999 Sardis: E&D 1A22 & 24 Bkr Rplferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OtherTaxMember 2022-01-012022-12-31 C008999 9C01- State Line Exploration- 3-pha 2022-01-012022-12-31 C008999 2020 - Focus - FC20M048 - Madison - 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR5 - New Buiferc:ElectricUtilityMember 2022-12-31 C008999 UPIC-Madison Co -Baleigh Dr.-Glendaferc:ElectricUtilityMember 2022-12-31 C008999 JACKSON/SOUTH, Distribution, Unattended 2022-01-012022-12-31 C008999 DELTA SWYD, Transmission, Unattended 2022-01-012022-12-31 C008999 Unit Power Cost Recovery Rider Under-Recovery MPSC Docket No. 2014-UN-132 2022-01-012022-12-31 C008999 State Income Tax, State Tax, , 2022-01-012022-12-31 C008999 C6ML300051: Flowers - Openwood 115kferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 Amort April 2021-Mar 2022 2021-12-31 C008999 UPIC-Canton-Oakfield Blvd- Stillhouferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 HAINING ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 FICA, Federal Tax, , 2021-12-31 C008999 C-29 Large General Service 2022-01-012022-12-31 C008999 ferc:SulfurDioxideMember 2021-12-31 C008999 Other expenses incurred in connection with various filings before the MPSC 2022-12-31 C008999 JACKSON - E. CAPITOL ST. - CITY OFferc:ElectricUtilityMember 2022-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2022-01-012022-12-31 C008999 Pine Tree Substation T&D D-Scoping 2022-01-012022-12-31 C008999 Electric Line Justificantion Extension 2022-12-31 C008999 ferc:FranchiseTaxMember 2022-01-012022-12-31 C008999 3.85% Series 2 2022-01-012022-12-31 C008999 ferc:UnemploymentTaxMember 2021-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2022-12-31 C008999 Changes in money pool payable - net 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,3 - UG Neferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Brookhaven Upgrade Transformerferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 FLOWERS, Distribution, Unattended 2022-01-012022-12-31 C008999 FTO - Flora Transmission Office 2022-01-012022-12-31 C008999 GLOSTER, Distribution, Unattended 2022-12-31 C008999 Canton Rd:  Install Circuit Swi, Re 2022-01-012022-12-31 C008999 EMI New Nuclear, LLC 2022-12-31 C008999 SPRING RIDGE ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 Ad Valorem Tax - MS, Other Ad Valorem Tax, , 2021-12-31 C008999 GM-Vicksburg SE Guild 5F02-R1, R2,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Entergy Power & Light Company 2022-12-31 C008999 YANDELL RD, Distribution, Unattended 2022-01-012022-12-31 C008999 C6ML300042: Ray Braswell - Clintonferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GS-299 General Lighting and Power 2022-01-012022-12-31 C008999 BOGALUSA 500, FRANKLIN EHV - [5521], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 7% 2022-01-012022-12-31 C008999 C6ML300002: Horn Lake - DeSoto 115kferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Federal Income Tax, Federal Tax, , 2022-01-012022-12-31 C008999 LELAND, Distribution, Unattended 2022-12-31 C008999 RANKIN, Distribution, Unattended 2022-12-31 C008999 JACKSON/EAST, Distribution, Unattended 2022-12-31 C008999 ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2022-12-31 C008999 EMI: Camlin Pilot Franklin EHVferc:ElectricUtilityMember 2022-12-31 C008999 TINNIN RD, NORREL 230 - [2339], Wood H-Frame, 1272 ACSR 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMemberferc:NextTwelveMonthsMember 2022-01-012022-12-31 C008999 ferc:OtherTaxesAndFeesMember 2022-12-31 C008999 CO1 Additional Warehouse With Contferc:ElectricUtilityMember 2022-12-31 C008999 GREENBROOK, Distribution, Unattended 2022-12-31 C008999 Miscellaneous 2022-01-012022-12-31 C008999 Build New Grenada Industrial 115kVferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 FootnoteDataAbstract 2022-01-012022-12-31 C008999 EMI: Camlin Pilot (Ray Braswell)ferc:ElectricUtilityMember 2022-12-31 C008999 TYLERTOWN, Distribution, Unattended 2022-12-31 C008999 Executive Vice President and General Counsel 2022-01-012022-12-31 C008999 Other expenses incurred in connection wiht various filings before the FERC 2022-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284) 2022-01-012022-12-31 C008999 ROSEDALE [MS], Distribution, Unattended 2022-12-31 C008999 SW2 - EDE-Bill Syst Contr Repo Inte 2022-01-012022-12-31 C008999 MAGEE, Distribution, Unattended 2022-12-31 C008999 EML C Spire - Northern Route 2022-01-012022-12-31 C008999 WHITFIELD, Distribution, Unattended 2022-01-012022-12-31 C008999 2022 Dist Capital Tools EMLferc:ElectricUtilityMember 2022-12-31 C008999 GETWELL, BYHALIA 230KV LN 241 [2341], Steel Pole, 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR4 - New Bui 2022-01-012022-12-31 C008999 See Footnoteferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Sunflower Betterment Spend Approach 2022-01-012022-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:Quarter4Member 0 2022-01-012022-12-31 C008999 ferc:PayrollTaxMember 2021-12-31 C008999 EMI 2022 Nov Storm Dist Ops - MSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 3.5% Series 1 2022-01-012022-12-31 C008999 ROXIE, Distribution, Unattended 2022-12-31 C008999 GRAND GULF DISTRIBUTION, Distribution, Unattended 2022-12-31 C008999 2.55% Series 2022-01-012022-12-31 C008999 C6ML300057: East Jackson - Fannin R 2022-01-012022-12-31 C008999 2023-Madison-Canton-Fac Relocation 2022-01-012022-12-31 C008999 2022 Customer NPSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 OTHER PRODUCTION PLANTferc:ElectricUtilityMember 2022-12-31 C008999 COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022 2022-01-012022-12-31 C008999 ferc:IncomeTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:RealEstateTaxMember 2022-01-012022-12-31 C008999 Other 2022-12-31 C008999 FRANKLIN EHV, Transmission, Unattended 2022-12-31 C008999 ferc:SulfurDioxideMemberferc:NextTwelveMonthsMember 2022-12-31 C008999 ferc:SalesAndUseTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132 2021-12-31 C008999 Term Loan 2022-01-012022-12-31 C008999 MEADVILLE, Distribution, Unattended 2022-12-31 C008999 VICKSBURG/EAST SS, Transmission, Unattended 2022-12-31 C008999 Add Ckt. 9A06  to Poleline for Seco 2022-01-012022-12-31 C008999 Defined Benefit Pension & Other Post Retirement Plans 2022-01-012022-12-31 C008999 GM - Guild 33 - FA06 - Rebuild - Cl 2022-01-012022-12-31 C008999 Madison 115kV - Add 2nd Transformerferc:ElectricUtilityMember 2022-12-31 C008999 Gerald Andrus Oil 2022-01-012022-12-31 C008999 Gas Baxter Wilson 2022-01-012022-12-31 C008999 DSL-16 Directional Security  Lighting 2022-01-012022-12-31 C008999 EML: 115-13.8 | 20MVA (Marvell)ferc:ElectricUtilityMember 2022-12-31 C008999 3.12 Upgrade/Fault Location 2022-01-012022-12-31 C008999 GRANTS FERRY, Distribution, Unattended 2022-12-31 C008999 Lakeover: Replace J9234 Breakerferc:ElectricUtilityMember 2022-12-31 C008999 ferc:NitrogenOxideMember Purchases/Transfers: 2022-01-012022-12-31 C008999 Electric Line Justificantion Extension 2022-01-012022-12-31 C008999 Energy Efficiency Rider Under-Recovery 2022-01-012022-12-31 C008999 Brookhaven Upgrade Transformer 2022-01-012022-12-31 C008999 ferc:FuelTaxMember 2022-01-012022-12-31 C008999 UPIC-Madison-Deweese Rd.-Westlake Mferc:ElectricUtilityMember 2022-12-31 C008999 Corporate Franchise Tax-AR, Franchise Tax, , 2022-12-31 C008999 10%ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F02-IA1; 5F0ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 BYHALIA, Distribution, Unattended 2022-01-012022-12-31 C008999 2022-MADISON-CHARITY CHURCH-RELOCATferc:ElectricUtilityMember 2022-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CATLETT, Distribution, Unattended 2022-12-31 C008999 HIGHWAY - GRANTS FERRY PARKWAY RELO 2022-01-012022-12-31 C008999 EML: 115-13.8kV | 20MVA LTC 2022-01-012022-12-31 C008999 DSL-16 Directional Security  Lighting 2022-01-012022-12-31 C008999 Vicksburg N: Rpl 115KV Bus Diff Panferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SHELBY SS, Transmission, Unattended 2022-01-012022-12-31 C008999 EMI New Nuclear, LLC 2022-12-31 C008999 SE21-004V EMI Sycamore Wakefield ROferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:PayrollTaxMember 2022-01-012022-12-31 C008999 Relocate Facilities W Capitol Stferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 FERNWOOD, Distribution, Unattended 2022-12-31 C008999 Franchise - City, Local Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 JACKSON/NORTH, Distribution, Unattended 2022-01-012022-12-31 C008999 Other expenses incurred in connection with MISO and other transmission related FERC dockets 2022-12-31 C008999 PowerPlan Upgrade 2022 2022-01-012022-12-31 C008999 EDF Trading North America, LLC , OS , 2022-01-012022-12-31 C008999 10%ferc:ElectricUtilityMember 2022-12-31 C008999 C6ML300036:  Nitta Yuma - Rolling F 2022-01-012022-12-31 C008999 ferc:JuneMember 0 2022-01-012022-12-31 C008999 Mississippi Power & Light Co. 2022-12-31 C008999 RAYMOND, Distribution, Unattended 2022-12-31 C008999 3.75% Series 2022-01-012022-12-31 C008999 SPO EMISunflowerCoSolarBOTTransactnferc:ElectricUtilityMember 2022-12-31 C008999 JONESTOWN SS, Transmission, Unattended 2022-12-31 C008999 Mississippi ITCferc:OtherUtilityOrNonutilityMember 2022-01-012022-12-31 C008999 Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132 2022-01-012022-12-31 C008999 Grand Gulf Over-Recovery MPSC Docket No. 1984- 2021-12-31 C008999 NATCHEZ/SOUTH, Distribution, Unattended 2022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff, Docket No. ER13-1508 2022-01-012022-12-31 C008999 ferc:FuelTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Mississippi Power & Light Co. 2022-01-012022-12-31 C008999 INDIANOLA 230/115 SUB, Transmission, Unattended 2022-12-31 C008999 LIBERTY, Distribution, Unattended 2022-12-31 C008999 Rankin 115kV Sub - Add Line Bay 2022-01-012022-12-31 C008999 Rotating Load Shed Software Imp 2022-01-012022-12-31 C008999 MCCOMB/WEST, Distribution, Unattended 2022-12-31 C008999 GRAND GULF TRANSMISSION, Transmission, Unattended 2022-12-31 C008999 2020 - RANKIN - AIRPORT - 6A04 - 55 2022-01-012022-12-31 C008999 2022-01-012022-03-31 C008999 HL-21 Public Highway & Park Lighting 2022-01-012022-12-31 C008999 Mark-to-Market 2021-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2022-12-31 C008999 State Unemployment Tax, Unemployment Tax, , 2021-12-31 C008999 SE21-004V EMI Sycamore Wakefield RO 2022-01-012022-12-31 C008999 Asset Suite/AIMM Repl - Supply Chai 2022-01-012022-12-31 C008999 Pine Tree Substation T&D D-Scopingferc:ElectricUtilityMember 2022-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2022-01-012022-12-31 C008999 Vicksburg N: Rpl 115KV Bus Diff Pan 2022-01-012022-12-31 C008999 Rankin Industrial - OH to UG Highwa 2022-01-012022-12-31 C008999 Entergy Mississippi, LLCferc:MarchMember 2022-01-012022-12-31 C008999 2021-01-012021-12-31 C008999 MISO Sch 2 Reactive 2022-01-012022-09-30 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022 2022-12-31 C008999 EMPLOYMENT TAXES (Account 40811) 2022-01-012022-12-31 C008999 BEECH GROVE SS, Transmission, Unattended 2022-01-012022-12-31 C008999 , , , 2022-12-31 C008999 A(3), Distribution Automation 2022-01-012022-12-31 C008999 ferc:OtherPropertyTaxMember 2022-01-012022-12-31 C008999 GREENVILLE, Distribution, Unattended 2022-12-31 C008999 SIEM Optimization 2022-01-012022-12-31 C008999 C6ML300080:  Flora - Little Yazoo ( 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMemberferc:CurrentYearMember 2022-12-31 C008999 Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 - Amort pd Aug 2022 thru June 2023 2021-12-31 C008999 EDWARDS-JACKSON STREET-RELOCATE REGferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 COLDWATER, Distribution, Unattended 2022-12-31 C008999 ferc:SulfurDioxideMemberferc:CurrentYearMember 2021-12-31 C008999 2022-01-012022-12-31 C008999 EML C Spire - Northern Routeferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GREENVILLE/SOUTHEAST, Distribution, Unattended 2022-01-012022-12-31 C008999 ScheduleGeneratingPlantStatisticsAbstract 2022-01-012022-12-31 C008999 CHOCTAW, Transmission, Unattended 2022-01-012022-12-31 C008999 BOVINA, Distribution, Unattended 2022-01-012022-12-31 C008999 DREW [MS], Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - FDR3 -  New Buferc:ElectricUtilityMember 2022-12-31 C008999 Mannsdale 230kV Substationferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 IPS-26 Irrigation Pumping Power 2022-01-012022-12-31 C008999 2022 Woodrow Wilson Relocationferc:ElectricUtilityMember 2022-12-31 C008999 Other 2021-01-012021-12-31 C008999 T&D - Snowden Park - FDR5 - New Bui 2022-01-012022-12-31 C008999 Federal Income Tax, Federal Tax, , 2022-12-31 C008999 UPIC-Madison-Deweese Rd.-Westlake Mferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:OtherTaxesAndFeesMember 2021-12-31 C008999 ENID, Distribution, Unattended 2022-12-31 C008999 SH21-011V NRT - Multiphase Additionferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 GREENVILLE/NORTH, Distribution, Unattended 2022-12-31 C008999 STRINGTOWN, Distribution, Unattended 2022-12-31 C008999 SW-Network Access Control Authenticferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Build New Grenada Industrial 115kVferc:ElectricUtilityMember 2022-12-31 C008999 GRENADA/SOUTH, Transmission, Unattended 2022-12-31 C008999 CLEVELAND [MS], Distribution, Unattended 2022-12-31 C008999 3.5% Series 2 2022-01-012022-12-31 C008999 ferc:FederalTaxMember 2021-12-31 C008999 IBM MRO IO Entergy Interfaceferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMemberferc:TwoYearsMember 2022-12-31 C008999 SL-37 Municipal Street Lighting 2022-01-012022-12-31 C008999 Getwell-Twinkletown 230kV Cut-In 2022-01-012022-12-31 C008999 Long-Term Incentive Plan 2021-12-31 C008999 WOLF CREEK, CHOCTAW 500 - [5015], Steel Pole, 954 ACSR 2022-01-012022-12-31 C008999 STRINGTOWN, Distribution, Unattended 2022-01-012022-12-31 C008999 JACKSON/NORTHWEST, Distribution, Unattended 2022-01-012022-12-31 C008999 LARSON ST/JACKSON, Distribution, Unattended 2022-01-012022-12-31 C008999 Independence Oil 2022-01-012022-12-31 C008999 SH21-012V Lewisburg School Projectferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)ferc:ElectricUtilityMember 2022-12-31 C008999 TUNICA, Distribution, Unattended 2022-12-31 C008999 ferc:NovemberMember 0 2022-01-012022-12-31 C008999 10% 2022-01-012022-12-31 C008999 SW-Facilities Ratings WS-NERC Repferc:ElectricUtilityMember 2022-12-31 C008999 ferc:IncomeTaxMember 2022-01-012022-12-31 C008999 CF Industries Nitrogen, LLC , OS , 2022-01-012022-12-31 C008999 President and Chief Executive Officer of Entergy Mississippi 2022-01-012022-12-31 C008999 MISO Sch 2 Reactive 2022-01-012022-06-30 C008999 ferc:OtherLicenseAndFeesTaxMember 2021-12-31 C008999 Derivative Instruments and Hedging Activities 2022-01-012022-12-31 C008999 TERRY, Distribution, Unattended 2022-12-31 C008999 Terry:  E&D 7B24 & 7B03 Bkr Rpl 2022-01-012022-12-31 C008999 MADISON, Distribution, Unattended 2022-01-012022-12-31 C008999 State Use Tax, Sales And Use Tax, , 2022-12-31 C008999 Ad Valorem Tax - 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SOUTHAVEN - PLUM POINT - CHUferc:ElectricUtilityMember 2022-12-31 C008999 Federal Excise Tax, Federal Tax, , 2022-01-012022-12-31 C008999 2022 MISO Predictive Analyticsferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 MIDNIGHT, Distribution, Unattended 2022-12-31 C008999 PELAHATCHIE, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SPO EML SunflowerTaxEquityPartneshpferc:ElectricUtilityMember 2022-12-31 C008999 T&D - Snowden Park - FDR1,2 - Rebuiferc:ElectricUtilityMember 2022-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2022-01-012022-12-31 C008999 ScheduleTransmissionOfElectricityByIsoOrRtoAbstract 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR3 -  New Bu 2022-01-012022-12-31 C008999 Increases (Decreases) from Sales of Donations Received from Stockholders 2022-01-012022-12-31 C008999 0, 0 2022-01-012022-12-31 C008999 MENDENHALL, Distribution, Unattended 2022-01-012022-12-31 C008999 OTHER TRANSMISSION LINES PLANTferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Canton Rd:  Install Circuit Swi, Referc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EML: Camlin Pilot - Baxter Wilsonferc:ElectricUtilityMember 2022-12-31 C008999 Midnight: rpl Oil Pump on J0346ferc:ElectricUtilityMember 2022-12-31 C008999 CLARKSDALE, Distribution, Unattended 2022-01-012022-12-31 C008999 MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl) 2022-01-012022-12-31 C008999 ferc:NitrogenOxideMember Allowances Used 2022-01-012022-12-31 C008999 MP-22 Municipal Pumping Power Service 2022-01-012022-12-31 C008999 RITCHIE, MOON LAKE 230 - [6320], Wood H-Frame, 1947.5 ACSR 2022-01-012022-12-31 C008999 Gerald Andrus - Tinnin Rd 230kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F02-R1, R2,ferc:ElectricUtilityMember 2022-12-31 C008999 BROOKHAVEN-905 INDUSTRIAL PARK RD N 2022-01-012022-12-31 C008999 Vicksburg Openwd 115kVSub-AddTransfferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198 2021-12-31 C008999 BRICKYARD, Distribution, Unattended 2022-12-31 C008999 Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020 2022-01-012022-12-31 C008999 LELAND, Distribution, Unattended 2022-01-012022-12-31 C008999 ISES Acquisition Adjustment 2021-12-31 C008999 GM-Guild 33-FJ05-Rebuild-Hickory Ri 2022-01-012022-12-31 C008999 VICKSBURG/OPENWOOD, Distribution, Unattended 2022-01-012022-12-31 C008999 Northpark: Add 230/115kV-400MVA Aut 2022-01-012022-12-31 C008999 BOLTON, Distribution, Unattended 2022-01-012022-12-31 C008999 Gerald Andrus Gas 2022-01-012022-12-31 C008999 Madison 115kV Second Xfmr T&Dferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Attachments Data System (ADS)ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:FederalInsuranceTaxMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Mannsdale 230kV Substationferc:ElectricUtilityMember 2022-12-31 C008999 ROBINSON ROAD/JACKSON, Distribution, Unattended 2022-12-31 C008999 Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff, Docket No. ER19-747 2022-01-012022-12-31 C008999 GREENVILLE/MIDTOWN, Distribution, Unattended 2022-12-31 C008999 BROOKHAVEN, Distribution, Unattended 2022-12-31 C008999 JACKSON/WATERWORKS, Distribution, Unattended 2022-12-31 C008999 GM-Vicksburg SE Guild 5F02-R1, R2, 2022-01-012022-12-31 C008999 UPIC-Madison Co -Baleigh Dr.-Glenda 2022-01-012022-12-31 C008999 BATESVILLE [MS], Transmission, Unattended 2022-01-012022-12-31 C008999 C-29 Large General Service 2022-01-012022-12-31 C008999 Privilege License, Other Taxes, , 2022-12-31 C008999 Power Management Rider Over-Recovery MPSC Docket 2022-01-012022-12-31 C008999 Madison-Lake Village Drive-Reunionferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 2021 Planning MD21-002A Rebuild R1ferc:ElectricUtilityMember 2022-12-31 C008999 LEXINGTON, Distribution, Unattended 2022-01-012022-12-31 C008999 Midnight: rpl Oil Pump on J0346 2022-01-012022-12-31 C008999 SOUTHAVEN - CITY WIDE LED CONVERSIO 2022-01-012022-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3ferc:ElectricUtilityMember 2022-12-31 C008999 ferc:FederalInsuranceTaxMember 2022-01-012022-12-31 C008999 Pwr Gen Remote Ops Project 2022-01-012022-12-31 C008999 Group President Utility Operations 2022-01-012022-12-31 C008999 Greenwood-Itta Bena 115Kv Cut-In 2022-01-012022-12-31 C008999 CATLETT, YANDELL RD 230 - [2343], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 UFL-16 Urban Flood Lighting 2022-01-012022-12-31 C008999 ferc:ThreeYearsMemberferc:SulfurDioxideMember 2022-12-31 C008999 EML: 115-13.8kV | 20MVA LTCferc:ElectricUtilityMember 2022-12-31 C008999 A1A - GE LTSA Budget Cap 2020-2024ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 RANKIN, Transmission, Unattended 2022-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2022-12-31 C008999 Other 2021-01-012021-12-31 C008999 C6ML300002: Horn Lake - DeSoto 115k 2022-01-012022-12-31 C008999 2023-Madison-Canton-Fac Relocationferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 State Unemployment Tax, Unemployment Tax, ,ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ELLIOTT SS, Transmission, Unattended 2022-01-012022-12-31 C008999 LIVINGSTON ROAD/JACKSON, Distribution, Unattended 2022-12-31 C008999 T&D - Snowden Park - FDR3,4,5 - Newferc:ElectricUtilityMember 2022-12-31 C008999 Lakeover-Hinds 230kV CAPferc:ElectricUtilityMember 2022-12-31 C008999 SILVER CREEK, Distribution, Unattended 2022-01-012022-12-31 C008999 EML: 115kV|40kA|3000A Blue Breakerferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 JACKSON-VALLEY PARK II-PROVIAS CONSferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 OTHER PRODUCTION PLANTferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 ferc:ElectricPlantHeldForFutureUseMemberferc:ElectricUtilityMember 2021-12-31 C008999 Non-Expense Accrued Labor 2022-12-31 C008999 BRICKYARD, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:OtherStateTaxMember 2021-12-31 C008999 ferc:DistributionPlantMemberferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SCHLATER, Distribution, Unattended 2022-12-31 C008999 ferc:FederalTaxMember 2022-12-31 C008999 REX BROWN 230 SWYD, Transmission, Unattended 2022-12-31 C008999 LAKEOVER, REX BROWN (EAST) 230 - [6184], Steel Tower, 1272 ACSR 2022-01-012022-12-31 C008999 CO1 LTSA Capitalizationferc:ElectricUtilityMember 2022-12-31 C008999 ferc:PayrollTaxMember 2022-12-31 C008999 Federal Uemployment Tax, Federal Tax, , 2022-12-31 C008999 PICKENS, Distribution, Unattended 2022-01-012022-12-31 C008999 Asset Retirement Obligation - Coal 2022-01-012022-12-31 C008999 Digital LIHEAPferc:ElectricUtilityMember 2022-12-31 C008999 ATTALA, Distribution, Unattended 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F03-N6, FSW1ferc:ElectricUtilityMember 2022-12-31 C008999 RAY BRASWELL EHV, Transmission, Unattended 2022-12-31 C008999 See Footnote Detailferc:ElectricUtilityMember 2021-12-31 C008999 FREEPORT, Transmission, Unattended 2022-12-31 C008999 HORN LAKE, Distribution, Unattended 2022-01-012022-12-31 C008999 Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 Amort April 2021-Mar 2022 2022-01-012022-12-31 C008999 ferc:FederalTaxMember 2022-01-012022-12-31 C008999 IP-33 Ice Manufacturing Plant Power 2022-01-012022-12-31 C008999 DESOTO, Distribution, Unattended 2022-01-012022-12-31 C008999 Video Management Solution Project 2022-01-012022-12-31 C008999 C6ML300039: Desoto - Walls 115kV CAferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 EDWARDS-JACKSON STREET-RELOCATE REG 2022-01-012022-12-31 C008999 2020 Planning CL20-005V Rep A1, RRE 2022-01-012022-12-31 C008999 EML Public EV Charging Pilotferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 HAINING ROAD, Distribution, Unattended 2022-12-31 C008999 FICA, Federal Tax, , 2022-12-31 C008999 ferc:NitrogenOxideMemberferc:CurrentYearMember 2022-01-012022-12-31 C008999 Choctaw 2022-01-012022-12-31 C008999 Vicksburg Openwd 115kVSub-AddTransf 2022-01-012022-12-31 C008999 Clinton 115 kV Sub - Install T-Brkr 2022-01-012022-12-31 C008999 CARTHAGE (MS), Distribution, Unattended 2022-12-31 C008999 2020 Planning CL20-005V Rep A1, RREferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 IPS-26 Irrigation Pumping Power 2022-01-012022-12-31 C008999 3.1% Series 2022-01-012022-12-31 C008999 ferc:StateTaxMember 2021-12-31 C008999 Vegetation Management Rider MPSC Docket No. 2018-UN-205 2022-01-012022-12-31 C008999 EMI: Camlin Pilot (Lakeover) 2022-01-012022-12-31 C008999 MAGEE, Distribution, Unattended 2022-01-012022-12-31 C008999 AIRPORT/JACKSON, Distribution, Unattended 2022-12-31 C008999 JACKSON - E. CAPITOL ST. - CITY OF 2022-01-012022-12-31 C008999 SENATOBIA, Distribution, Unattended 2022-01-012022-12-31 C008999 ferc:LandAndRightsMember Land and Land Rights Under $250,000 2022-12-31 C008999 Entergy Arkansas, LLC , LU , 2022-01-012022-12-31 C008999 UNDISTRIBUTED OVERHEADS:ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 UPIC-Southaven-Rasco Rd-Johnny Cole 2022-01-012022-12-31 C008999 RFL-16 Rural Flood Lighting 2022-01-012022-12-31 C008999 Inverness replace transformer J0135ferc:ElectricUtilityMember 2022-12-31 C008999 See Footnoteferc:ElectricUtilityMember 2021-12-31 C008999 GS-299 MS Gen. Lghtg & Pwr Muni. Service 2022-01-012022-12-31 C008999 Hinds 2022-12-31 C008999 MILL STREET, Distribution, Unattended 2022-12-31 C008999 HIGHWAY - GRANTS FERRY PARKWAY RELOferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 BELZONI, Distribution, Unattended 2022-01-012022-12-31 C008999 EMI: Camlin Pilot (Lakeover)ferc:ElectricUtilityMember 2022-12-31 C008999 OTHER GENERAL & INTANGIBLE PLANT 2022-01-012022-12-31 C008999 T&D - Snowden Park - FDR1,2 - Rebuiferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Term Loan 2022-12-31 C008999 McAdams Relay Imprv. SPOFferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SW-Network Access Control Authenticferc:ElectricUtilityMember 2022-12-31 C008999 See footnote for allocation method details, 2022-01-012022-12-31 C008999 UFL-16 Urban Flood Lighting 2022-01-012022-12-31 C008999 AD21M004 - FOCUS - 1D02 - K1511ferc:ElectricUtilityMember 2022-12-31 C008999 TWINKLETOWN, Distribution, Unattended 2022-12-31 C008999 ferc:JanuaryMember Entergy Mississippi, LLC 2022-01-012022-12-31 C008999 FLORA, Distribution, Unattended 2022-01-012022-12-31 C008999 MISO Sch 2 Reactive 2022-01-012022-12-31 C008999 2020 - Focus - FC20M048 - Madison -ferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 CATLETT, SOUTH CANTON 230 KV LN 244 [2392], Steel Pole, 2022-01-012022-12-31 C008999 ScheduleCapitalStockExpenseAbstract 2022-01-012022-12-31 C008999 , , , 2022-01-012022-12-31 C008999 UNDISTRIBUTED OVERHEADS:ferc:ElectricUtilityMember 2022-12-31 C008999 , , , 2021-12-31 C008999 Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205 2022-01-012022-12-31 C008999 CRYSTAL SPRINGS, Distribution, Unattended 2022-12-31 C008999 BAXTER WILSON, RAY BRASWELL 500 - [6880], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 EMI New Nuclear, LLCferc:CapitalContributionMember 2022-12-31 C008999 Attala 2022-12-31 C008999 2021 - SENATOBIA - LULA - 1K01 - Q1 2022-01-012022-12-31 C008999 Entergy Mississippi, LLCferc:DecemberMember 2022-01-012022-12-31 C008999 2022 Data Analytics Platform - AWSferc:ElectricUtilityMember 2022-12-31 C008999 2022-GRENADA-MILWAUKEE TOOL PART 3 2022-01-012022-12-31 C008999 OTHER TRANSMISSION LINES PLANT 2022-01-012022-12-31 C008999 TF-23 Traffic Control Signals 2022-01-012022-12-31 C008999 PAL-17 Private Area Lighting 2022-01-012022-12-31 C008999 MPSC Docket No. 2008-UN-381 - Power Management Rider Expense 2022-01-012022-12-31 C008999 GM-Vicksburg SE Guild 5F02-IREG1, Iferc:ElectricUtilityMember 2022-12-31 C008999 SH21-012V Lewisburg School Project 2022-01-012022-12-31 C008999 NATCHEZ/INDUSTRIAL PARK, Distribution, Unattended 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER17-1549 2022-01-012022-12-31 C008999 Entergy Mississippi, LLCferc:JuneMember 2022-01-012022-12-31 C008999 Other 2022-01-012022-12-31 C008999 UPIC-Canton-Oakfield Blvd- Stillhou 2022-01-012022-12-31 C008999 Entergy Services, LLC, Other Allocated Tax, , 2021-12-31 C008999 State Excise Tax, Excise Tax, , 2021-12-31 C008999 SH21-013A Lewisburg School Scoping 2022-01-012022-12-31 C008999 Ad Valorem Tax - AR, Other Ad Valorem Tax, , 2022-01-012022-12-31 C008999 FRANKLIN, GRAND GULF 500 - [5640], Steel Tower, 954 ACSR 2022-01-012022-12-31 C008999 EML: AC Reactor for Ray Braswell 2022-01-012022-12-31 C008999 GEORGETOWN [MS], Distribution, Unattended 2022-12-31 C008999 ferc:UnappriatedUndistributedSubsidiaryEarningsMember EMI New Nuclear, LLC 2022-01-012022-12-31 C008999 MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132 2022-12-31 C008999 Franklin-GGNS 500Kv Phase Swa 2022-01-012022-12-31 C008999 OTHER TRANSMISSION & DISTRIBUTION SUBSferc:ElectricUtilityMember 2022-12-31 C008999 MPSC Docket No. 2008-UN-381 - Power Management Rider Expense 2022-12-31 C008999 Other Property Under $250,000ferc:OtherPropertyMember 2022-01-012022-12-31 C008999 Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff, Docket No. ER18-1260 2022-01-012022-12-31 C008999 Pwr Gen Remote Ops Projectferc:ElectricUtilityMember 2022-12-31 C008999 2020 Planning CL20-005V New Build Nferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 SE-29 State Institutions 2022-01-012022-12-31 C008999 BROOKHAVEN/SOUTH, Distribution, Unattended 2022-12-31 C008999 UPIC-Canton-Oakfield Blvd- Stillhouferc:ElectricUtilityMember 2022-12-31 C008999 PGen Smart Procedures 2022-01-012022-12-31 C008999 Accumulated Miscellaneous Operating Provisions (Account 2284)ferc:DirectPayrollDistributionMember 2022-01-012022-12-31 C008999 2022 Woodrow Wilson Relocation 2022-01-012022-12-31 C008999 ferc:StateTaxMember 2022-01-012022-12-31 C008999 SOUTHAVEN - CITY WIDE LED CONVERSIOferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 UPIC-Hernando-Laughter Road S-Mille 2022-01-012022-12-31 C008999 Other 2022-01-012022-12-31 C008999 SUNNYBROOK, Distribution, Unattended 2022-01-012022-12-31 C008999 FANNIN ROAD, Distribution, Unattended 2022-01-012022-12-31 C008999 LED-2 LED Street and Area  Lighting 2022-01-012022-12-31 C008999 SOUTH CANTON, YANDEL RD 230 - [2314], Steel Pole, 1272 ACSR 2022-01-012022-12-31 C008999 ELLIOTT, Distribution, Unattended 2022-12-31 C008999 GRAND GULF TRANSMISSION, Transmission, Unattended 2022-01-012022-12-31 C008999 PRELIMINARY SURVEY & INVTG CH 2022-01-012022-12-31 C008999 9C01- State Line Exploration- 3-phaferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 Bowling Green - Durant 115kV CAPferc:ElectricUtilityMember 2022-01-012022-12-31 C008999 JONESTOWN, Distribution, Unattended 2022-01-012022-12-31 utr:kV utr:Mcf iso4217:USD utr:T utr:MW iso4217:USD utr:MMBTU iso4217:USD utr:bbl utr:mi utr:T utr:MWh xbrli:pure xbrli:pure utr:mi utr:MVA iso4217:USD utr:kWh iso4217:USD utr:Btu utr:kWh utr:kWh utr:Btu iso4217:USD utr:kW utr:bbl iso4217:USD utr:Mcf
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

Entergy Mississippi, LLC
Year/Period of Report

End of:
2022
/
Q4


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent

Entergy Mississippi, LLC
02 Year/ Period of Report


End of:
2022
/
Q4
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

308 East Pearl Street, Jackson, Mississippi 39201
05 Name of Contact Person

Gina G. Bellott
06 Title of Contact Person

Sr. Staff Accountant
07 Address of Contact Person (Street, City, State, Zip Code)

639 Loyola Avenue, New Orleans, Louisiana 70113
08 Telephone of Contact Person, Including Area Code

(504) 858-3276
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

04/13/2023
Annual Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Reginald T. Jackson
02 Title

Sr VP & Chief Accounting Officer
03 Signature

Reginald T. Jackson
04 Date Signed (Mo, Da, Yr)

04/13/2023
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
LIST OF SCHEDULES (Electric Utility)

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
NA
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
NA
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
NA
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
NA
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
NA
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
NA
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
NA
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
NA
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
NA
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
NA
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
NA
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
NA
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
NA
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
NA
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
NA
0
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
NA
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
NA
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Reginald T. Jackson

Senior Vice President and Chief Accounting Officer

639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
TX

Date of Incorporation:
2018-09-17

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

N/A

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Mississippi - Electric Utility Service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
As of December 31, 2022, all of the common membership interests in Entergy Mississippi are held by Entergy Utility Holding Company. As of December 31, 2022, Entergy Utility Holding Company's membership interests are held by:

     Entergy Corporation 3.6% 418,195 shares
Entergy Utility Affiliates 22.7% multiple securities
Entergy Utility Assets 30.4% 3,541,258 shares
Entergy Utility Enterprises 12.8% 1,493,077 shares
Entergy Utility Group 3.0% 350,173 shares
  EUHC Holdings 25.8% 3,006,086 shares
Unaffiliated third parties 1.7% multiple securities


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
EMI New Nuclear, LLC
100
2
Entergy Power & Light Company
100
3
The Light, Heat and Water Company of Jackson, Mississippi
100
4
Jackson Gas Light Company
100
5
Mississippi Power & Light Company
100


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
President and Chief Executive Officer of Entergy Mississippi
Haley R. Fisackerly
410,557
2
Chairman of the Board of Entergy Corporation
Leo P. Denault
3
Chief Executive Officer of Entergy Corporation (1)
Leo P. Denault
2022-11-01
4
Chief Executive Officer of Entergy Corporation (2)
Andrew S. Marsh
2022-11-01
5
Executive Vice President and Chief Financial Officer (1)
Andrew S. Marsh
2022-11-01
6
Executive Vice President and Chief Financial Officer (2)
Kimberly A. Fontan
2022-11-01
7
Executive Vice President and Chief Operating Officer of Entergy Corporation (1)
Paul D. Hinnenkamp
2022-08-12
8
Executive Vice President and Chief Operating Officer of Entergy Corporation (2)
Peter S. Norgeot, Jr.
2022-08-12
9
Executive Vice President and General Counsel
Marcus V. Brown
10
Group President Utility Operations
Roderick K. West
11
Senior Vice President and Chief Accounting Officer (1)
Kimberly A. Fontan
2022-11-01
12
Senior Vice President and Chief Accounting Officer (2)
Reginald T. Jackson
2022-11-01
13
Vice President and General Tax Counsel
Steven W. Brady


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(b) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(c) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(d) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(e) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(f) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(g) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(h) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(i) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(j) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(k) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.
(l) Concept: OfficerSalary
Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi
308 East Pearl Street, Jackson, MS 39201
false
false
2
Kimberly A. Fontan - Executive Vice President and Chief Financial Officer
639 Loyola Avenue, New Orleans, LA 70113
true
false
3
Roderick K. West - Group President Utility Operations
639 Loyola Avenue, New Orleans, LA 70113
true
false
4
Peter S. Norgeot, Jr. - Executive Vice President and Chief Operating Officer of Entergy Corporation
2017 Research Forest Drive, The Woodlands, TX 77380
true
false


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff
Docket No. ER13-1508
2
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER16-2199
3
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER18-1247
4
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER19-747
5
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-915
6
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1720
7
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-1997
8
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER21-2169
9
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER22-489
10
Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff
Docket No. ER22-2332
11
Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1
Docket No. ER13-948
12
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER14-649
13
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-358
14
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER15-1436
15
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-227
16
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER16-1322
17
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-215
18
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1549
19
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-1777
20
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-2579
21
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1260
22
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER18-1982
23
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-652
24
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER19-1503
25
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER17-827
26
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1449
27
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER20-1472
28
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-200
29
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-262
30
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER21-2693
31
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-1602
32
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-2202
33
Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff
Docket No. ER22-2562


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
03/15/2022
ER22-1351
(a)
EML Annual Informational MISO Attachment O Transmission Formula Rate Update


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfFiling
Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2020 update was filed on March 15, 2022 in Docket No. ER22-1351. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2021 through May 31, 2022 through the application of data for Calendar Year 2020 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
NONE


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1.None
2. None
3. None
4. None
5. None
6. See Entergy Mississippi's 2022 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, and utility support employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective October 16, 2019 through October 15, 2022. The Company and the Union agreed to a new contract effective October 15, 2022 through October 15, 2025. Effective October 16, 2022, the wage increase was 2.5%.

Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 15, 2019 through April 15, 2022. The Company and the Union agreed to a new contract effective April 16, 2022 through April 16, 2026. Effective April 16, 2022, the wage increase was 2.5%.

Effective April 1, 2022, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 3.0%.
9. See Entergy Mississippi’s 2022 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
12. See Entergy Mississippi's 2022 FERC Form 1 Notes to Financial Statements.
13. See Entergy Mississippi’s 2022 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2022.
14. Not applicable


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
6,948,265,708
6,616,604,360
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
169,802,754
95,935,092
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
7,118,068,462
6,712,539,452
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
(a)
2,105,185,734
(b)
1,991,077,854
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
5,012,882,728
4,721,461,598
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
5,012,882,728
4,721,461,598
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
5,025,426
5,076,754
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
513,554
549,813
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
95,822,307
2,242
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
34,459,021
48,885,707
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
134,793,200
53,414,890
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
25,507
28,264
36
SpecialDeposits
Special Deposits (132-134)
37
WorkingFunds
Working Fund (135)
139
38
TemporaryCashInvestments
Temporary Cash Investments (136)
809,835
47,595,970
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
99,503,754
84,047,722
41
OtherAccountsReceivable
Other Accounts Receivable (143)
34,563,849
14,608,590
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
2,471,515
7,209,104
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
37,673,103
42,993,614
45
FuelStock
Fuel Stock (151)
227
15,537,354
10,290,914
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
80,173,375
66,127,931
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
10,807
20,170
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
4,172,529
3,510,746
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
16,275,451
16,445,586
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
117,114
1,317
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
73,473,246
56,033,772
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
29,585
17,470
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
568,661
294,549
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
360,462,794
334,807,511
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
20,097,508
20,864,002
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
514,679,808
457,274,699
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
9,308,250
891,053
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
80,244
182,547
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
2,671,935
2,315,100
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
10,866,706
12,159,775
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
570,309,487
602,399,094
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
1,127,853,450
1,096,086,270
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
6,635,992,172
6,205,770,269


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $159,380,684.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $136,760,640.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
329,266,361
329,266,361
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
1,707,662,335
1,510,306,089
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
209,536
3,970
13
ReacquiredCapitalStock
(Less) Reaquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
2,037,138,232
1,839,568,480
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
2,195,000,000
2,195,000,000
19
ReacquiredBonds
(Less) Reaquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
150,000,000
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
12,262,053
12,719,332
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
6,458,523
6,865,924
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
2,350,803,530
2,200,853,408
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
23,701,837
18,247,593
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
33,644,644
33,185,707
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
3,800,680
4,426,225
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
32,584,563
33,927,919
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
64,000
416,001
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
7,797,108
10,314,948
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
36,423,706
32,662,555
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
38
AccountsPayable
Accounts Payable (232)
142,339,646
112,999,501
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
60,798,343
42,928,967
41
CustomerDeposits
Customer Deposits (235)
89,667,860
86,166,586
42
TaxesAccrued
Taxes Accrued (236)
262
279,673,086
158,851,699
43
InterestAccrued
Interest Accrued (237)
21,308,245
19,683,085
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
2,745,088
2,299,129
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
1,098,451
17,055,527
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
8,515,017
7,709,028
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
24,003,048
6,709,364
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
630,148,784
454,402,886
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
28,563,547
16,460,070
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
14,591,466
10,912,780
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
59,763,946
96,517,003
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
286,087,433
286,875,679
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reaquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
716,929,779
704,675,180
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
475,541,749
562,842,228
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
1,581,477,920
1,678,282,940
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
6,635,992,172
6,205,770,269


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
1,622,375,772
1,406,346,287
1,622,375,772
1,406,346,287
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
800,037,208
697,588,741
800,037,208
697,588,741
5
MaintenanceExpense
Maintenance Expenses (402)
320
94,799,001
84,691,764
94,799,001
84,691,764
6
DepreciationExpense
Depreciation Expense (403)
336
219,099,143
202,917,586
219,099,143
202,917,586
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
11,486
11,486
11,486
11,486
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
23,210,109
20,508,961
23,210,109
20,508,961
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
2,681,141
2,722,019
2,681,141
2,722,019
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
136,047,708
57,132,213
136,047,708
57,132,213
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
119,434,556
51,219,492
119,434,556
51,219,492
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
137,539,778
111,711,558
137,539,778
111,711,558
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
90,573,212
3,023,595
90,573,212
3,023,595
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
12,890,589
10,812,857
12,890,589
10,812,857
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
802,986,873
323,093,478
802,986,873
323,093,478
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
855,301,008
264,320,220
855,301,008
264,320,220
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
3,664,589
1,836,307
3,664,589
1,836,307
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
569,340
552,553
569,340
552,553
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
1,349,374,613
1,173,390,502
1,349,374,613
1,173,390,502
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
273,001,159
232,955,785
273,001,159
232,955,785
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
15,069
16,296
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
213,506
37
InterestAndDividendIncome
Interest and Dividend Income (419)
486,056
53,379
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
6,125,356
8,101,351
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
10,950,871
1,126,249
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
141,009
95,187
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
17,901,729
9,359,870
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
12,442
43,618
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
4,331,458
1,651,277
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
116,214
8,618
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
2,312,522
2,596,819
49
OtherDeductions
Other Deductions (426.5)
2,351,377
940,946
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
9,124,013
5,224,042
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
245
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
520,049
1,559,370
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
130,338
390,820
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
650,142
1,950,190
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
9,427,858
6,086,018
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
81,746,939
71,242,944
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
1,907,544
1,567,681
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
1,293,069
1,356,973
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
457,279
439,305
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
398,719
6,515
68
OtherInterestExpense
Other Interest Expense (431)
2,770,677
1,888,738
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
2,800,404
3,415,886
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
84,859,265
72,207,660
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
197,569,752
166,834,143
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
0
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
197,569,752
166,834,143


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report


End of:
2022
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
1,510,306,089
1,343,471,946
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
197,356,246
166,834,143
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
30.1
DividendsDeclaredCommonStock
Common equity distributions
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
1,707,662,335
1,510,306,089
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
1,707,662,335
1,510,306,089
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
3,970
3,970
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
213,506
51
DividendsReceived
(Less) Dividends Received (Debit)
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)
209,536
3,970


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
197,569,752
166,834,143
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
245,571,219
226,712,605
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt
3,200,613
2,924,654
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
52,314,135
58,773,258
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
3,664,589
1,836,307
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
65,844,707
10,262,223
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
19,953,667
3,317,479
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
9,363
26,384
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
169,656,068
8,588,815
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
57,405,109
112,943,072
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
788,246
32,356,159
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
6,125,356
8,101,351
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other working capital
5,051,952
1,939,790
18.2
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other
18,148,573
17,749,280
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
404,143,763
350,965,526
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
533,495,870
654,351,606
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
6,125,356
8,101,351
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
527,370,514
646,250,255
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
95,606,559
2,000
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Changes in money pool receivable - net
13,576,864
40,456,217
53.2
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other
(a)
1,273,314
49,048
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
610,673,523
686,659,424
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
149,266,350
398,284,127
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Change in credit borrowings - net
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
149,266,350
398,284,127
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other
(b)
10,474,657
1,539,205
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Changes in money pool payable - net
16,515,813
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
159,741,007
383,307,519
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
46,788,753
47,613,621
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
47,624,234
10,613
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
835,481
47,624,234


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other investing activities include:
2022 2021
Prefunded property insurance escrow ($363,159) $41,865 
Other special funds —  7,183 
Captive insurance deposit (910,155) — 
Total ($1,273,314) $49,048 
(b) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other financing activities include:
2022 2021
Customer Advances for Construction $12,103,477  $3,210,656 
Financing Leases (1,628,820) (1,671,451)
Total $10,474,657  $1,539,205 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:

Cash and Cash Equivalents at December 31, 2022
Cash (Account 131)$25,507 
Working Fund (Account 135)139 
Temporary Cash Investments (Account 136)809,835 
Total$835,481 
Supplemental Disclosure of Cash Flow Statement
Cash paid (received) during the period for:(in 000s)
Interest - net of amount capitalized$82,591 
Income Taxes($5,396)

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2021 data for the statement of retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.

GAAP requires that Entergy Mississippi consolidate MS Sunflower Partnership, LLC due to the significant influence it exerts as the managing member of the partnership, whereas Entergy Mississippi's investment in the partnership is presented in the FERC Form 1 as an equity-method investment. Additionally, GAAP requires Entergy Mississippi to record the earnings it receives from the partnership using the hypothetical-liquidation at book value (HLBV) method of accounting because the limited liability agreement forming the partnership stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Mississippi and the other investor in the partnership. In contrast, Entergy Mississippi recognizes its share in the partnership earnings based on its ownership-percentage in the partnership for reporting in the FERC Form 1.

C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2022. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.
"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
2022
2.7%
2.4%
3.6%
3.2%
3.1%
2.0%
2021
2.7%
2.4%
3.6%
3.2%
3.2%
1.9%
2020
2.6%
2.4%
3.5%
3.1%
3.1%
2.1%

Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $202.2 million as of December 31, 2022 and $188.5 million as of December 31, 2021. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of
accumulated depreciation of $0.5 million as of December 31, 2022 and $0.5 million as of December 31, 2021. Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2022.

As of December 31, 2022, construction expenditures included in accounts payable are $93.2 million for Entergy Arkansas, $154.3 million for Entergy Louisiana, $59.5 million for Entergy Mississippi, $11.2 million for Entergy New Orleans, $68.9 million for Entergy Texas, and $29 million for System Energy. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2022, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:
Generating Stations
Fuel Type
Total Megawatt Capability (a)
Ownership
Investment
Accumulated Depreciation
(In Millions)
Utility business:
Entergy Arkansas -
Independence
Unit 1
Coal
821
31.50%
$144
$107
Independence
Common Facilities
Coal
15.75%
$43
$31
White Bluff
Units 1 and 2
Coal
1,638
57.00%
$592
$397
Ouachita (b)
Common Facilities
Gas
66.67%
$173
$157
Union (c)
Common Facilities
Gas
25.00%
$29
$10
Entergy Louisiana -
Roy S. Nelson
Unit 6
Coal
518
40.25%
$299
$216
Roy S. Nelson
Unit 6 Common Facilities
Coal
22.73%
$22
$10
Big Cajun 2
Unit 3
Coal
540
24.15%
$149
$133
Big Cajun 2
Unit 3 Common Facilities
Coal
8.05%
$5
$3
Ouachita (b)
Common Facilities
Gas
33.33%
$91
$78
Acadia
Common Facilities
Gas
50.00%
$22
$2
Union (c)
Common Facilities
Gas
50.00%
$58
$12
Entergy Mississippi -
Independence
Units 1 and 2 and Common Facilities
Coal
1,242
25.00%
$292
$185
Entergy New Orleans -
Union (c)
Common Facilities
Gas
25.00%
$29
$9
Entergy Texas -
Roy S. Nelson
Unit 6
Coal
518
29.75%
$211
$122
Roy S. Nelson
Unit 6 Common Facilities
Coal
16.80%
$8
$3
Big Cajun 2
Unit 3
Coal
540
17.85%
$111
$86
Big Cajun 2
Unit 3 Common Facilities
Coal
5.95%
$4
$1
Montgomery County
Unit 1
Gas
903
92.44%
$744
$37
System Energy -
Grand Gulf (d)
Unit 1
Nuclear
1,400
90.00%
$5,427
$3,356
a.“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.
c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.
d.Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and
liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (i) are approved by a third-party regulator; (ii) are designed to recover the entities’ cost of providing the regulated services or products; and (iii) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers.

Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be returned to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement.

In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made.

Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.

Equity Method Investments
Entergy owned investments that were accounted for under the equity method of accounting because Entergy’s ownership level resulted in significant influence, but not control, over the investee and its operations. Entergy recorded its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions were charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis.

Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.
Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Regulatory activity regarding the Tax Cuts and Jobs Act

See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2022 and 2021 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.
2022
2021
(In Millions)
Entergy Arkansas (a)
$208.6
$177.6
Entergy Louisiana (b)
$327.3
$213.5
Entergy Mississippi
$143.2
$121.9
Entergy New Orleans (b)
$14.2
($3.5)
Entergy Texas
$258.1
$48.3

a.Includes $68.9 million in 2022 and $68.8 million in 2021 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Mississippi

Entergy Mississippi’s rate schedules include an energy cost recovery rider that is adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In November 2019, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation included $39.6 million of prior over-recovery flowing back to customers beginning February 2020. Entergy Mississippi’s balance in its deferred fuel account did not decrease as expected after implementation of the new factor. In an effort to assist customers during the COVID-19 pandemic, in May 2020, Entergy Mississippi requested an interim adjustment to the energy cost recovery rider to credit approximately $50 million from the over-recovered balance in the deferred fuel account to customers over four consecutive billing months. The MPSC approved this interim adjustment in May 2020 effective for June through September 2020 bills.

In November 2020, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an over-recovery of approximately $24.4 million as of September 30, 2020. In January 2021 the MPSC approved the proposed energy cost factor effective for February 2021 bills.

In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years, and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills.
SeeComplaints Against System Energy - System Energy Settlement with the MPSC” below for discussion of the settlement agreement filed with the FERC in June 2022. The settlement, which was contingent upon FERC approval, provides for a refund of $235 million from System Energy to Entergy Mississippi. In July 2022 the MPSC directed the disbursement of settlement proceeds, ordering Entergy Mississippi to provide a one-time $80 bill credit to each of its approximately 460,000 retail customers to be effective during the September 2022 billing cycle, and to apply the remaining proceeds to Entergy Mississippi’s under-recovered deferred fuel balance. In accordance with the MPSC’s directive, Entergy Mississippi provided approximately $36.7 million in customer bill credits as a result of the settlement. In November 2022, Entergy Mississippi applied the remaining settlement proceeds in the amount of approximately $198.3 million to Entergy Mississippi’s under-recovered deferred fuel balance. In November 2022 the FERC issued an order approving the System Energy settlement with the MPSC.

Entergy Mississippi had a deferred fuel balance of approximately $291.7 million under the energy cost recovery rider as of July 31, 2022, along with an over-recovery balance of $51.1 million under the power management rider. Without further action, Entergy Mississippi anticipated a year-end deferred fuel balance of approximately $200 million after application of a portion of the System Energy settlement proceeds, as discussed above. In September 2022, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider. Entergy Mississippi proposed five monthly incremental adjustments to the net energy cost factor designed to collect the under-recovered fuel balance as of July 31, 2022 and to reflect the recovery of a higher natural gas price. Entergy Mississippi also proposed five monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance as of July 31, 2022. In October 2022 the MPSC approved modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider. The MPSC approved dividing the energy cost recovery rider interim adjustment into two components that would allow Entergy Mississippi to 1) recover a natural gas fuel rate that is better aligned with current prices and 2) recover the estimated under-recovered deferred fuel balance as of September 30, 2022 over a period of 20 months. The MPSC approved six monthly incremental adjustments to the net energy cost factor designed to reflect the recovery of a higher natural gas price. The MPSC also approved six monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance. In accordance with the order of the MPSC, Entergy Mississippi did not file an annual redetermination of the energy cost recovery rider or the power management rider in November 2022. Entergy Mississippi’s November 2023 annual redetermination will not reflect any part of the estimated under-recovered deferred fuel balance as of September 30, 2022; it will only reflect any over/under recovery that accumulates after September 2022. The November 2024 annual redetermination will include the total deferred fuel balance, including any over- or under-recovery of the deferred fuel balance as of September 30, 2022.

Retail Rate Proceedings

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2020 Formula Rate Plan Filing

In March 2020, Entergy Mississippi submitted its formula rate plan 2020 test year filing and 2019 look-back filing showing Entergy Mississippi’s earned return for the historical 2019 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2020 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $24.6 million rate increase is necessary to reset Entergy
Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. The 2019 look-back filing compares actual 2019 results to the approved benchmark return on rate base and reflects the need for a $7.3 million interim increase in formula rate plan revenues. In accordance with the MPSC-approved revisions to the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2019 retail revenues, effective with the April 2020 billing cycle, subject to refund. In June 2020, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2020 test year filing showed that a $23.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. Pursuant to the joint stipulation, Entergy Mississippi’s 2019 look-back filing reflected an earned return on rate base of 6.75% in calendar year 2019, which is within the look-back bandwidth. As a result, there is no change in formula rate plan revenues in the 2019 look-back filing. In June 2020 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2020. In the June 2020 order the MPSC directed Entergy Mississippi to submit revisions to its formula rate plan to realign recovery of costs from its energy efficiency cost recovery rider to its formula rate plan. In November 2020 the MPSC approved Entergy Mississippi’s revisions to its formula rate plan providing for the realignment of energy efficiency costs to its formula rate plan, the deferral of energy efficiency expenditures into a regulatory asset, and the elimination of its energy efficiency cost recovery rider effective with the January 2022 billing cycle.

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through June 2022. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the
MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

2022 Formula Rate Plan Filing

In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing shows a $69 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $48.6 million. The 2021 look-back filing compares actual 2021 results to the approved benchmark return on rate base and reflects the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022.

In June 2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2022 test year filing that resulted in a total rate increase of $48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2021 look-back filing reflected an earned return on rate base of 5.99% in calendar year 2021, which is below the look-back bandwidth, resulting in a $34.3 million increase in the formula rate plan revenues on an interim basis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective in August 2022. In July 2022, Entergy Mississippi recorded regulatory credits of $22.6 million to reflect the effects of the joint stipulation. In August 2022 an intervenor filed a statutorily-authorized direct appeal to the Mississippi Supreme Court seeking review of the MPSC’s July 2022 order approving the joint stipulation confirming Entergy Mississippi’s 2022 formula rate plan filing. The rates that went into effect in August 2022 are not stayed or otherwise impacted while the appeal is pending.

In July 2022 the MPSC directed Entergy Mississippi to flow $14.1 million of the power management rider over-recovery balance to customers beginning in August 2022 through December 2022 to mitigate the bill impact of the increase in formula rate plan revenues.

2023 Formula Rate Plan Filing

Entergy Mississippi plans to file its look-back evaluation report in March 2023 that will compare actual 2022 results to the performance-adjusted allowed return on rate base. In fourth quarter 2022, Entergy Mississippi recorded a regulatory asset of $18.2 million in connection with the look-back feature of the formula rate plan to reflect that the 2022 estimated earned return was below the formula bandwidth.

COVID-19 Orders

In March 2020 the MPSC issued an order suspending disconnections for a period of sixty days. The MPSC extended the order on disconnections through May 26, 2020. In April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed
disconnecting service for residential customers with past-due balances that had not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and included those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. Entergy Mississippi began recovery of the bad debt expense deferral resulting from the COVID-19 pandemic over a three-year period with implementation of the interim formula rate plan rates in April 2022. As of December 31, 2022, Entergy Mississippi had a remaining regulatory asset of $9.8 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding.

After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision.

The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.

In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that
interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology.

In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal.

The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties.

Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million.

In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the
FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit.

In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:

Total refunds including interest
Payment/(Receipt)
(In Millions)
Principal
Interest
Total
Entergy Arkansas
$68
$67
$135
Entergy Louisiana
($30)
($29)
($59)
Entergy Mississippi
($18)
($18)
($36)
Entergy New Orleans
($3)
($4)
($7)
Entergy Texas
($17)
($16)
($33)

As described above, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

System Energy Settlement with the MPSC

In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorializes the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered. The settlement therefore limits System Energy’s overall refund exposure associated with the identified proceedings because they will be resolved completely as between the Entergy parties and the MPSC.

The FERC proceedings that are resolved as between the Entergy parties and the MPSC include the return on equity and capital structure complaints, the Grand Gulf Sale-leaseback renewal complaint and uncertain tax position rate base issue, the Unit Power Sales Agreement complaint, and the Grand Gulf prudence complaint, all of which are discussed above. They also include the proceedings concerning System Energy’s return of excess accumulated deferred income taxes after the Tax Cuts and Jobs Act and the proceedings established to address System Energy’s October 2020 and December 2020 Federal Power Act section 205 filings to provide credits to customers related to the IRS’s decision as to the uncertain decommissioning tax position, also as discussed. The settlement also resolves the MPSC’s involvement in the formal challenge filed by the retail regulators of System
Energy’s customers in connection with the implementation of the Unit Power Sales Agreement annual formula rate protocols for the 2020 test year, which is discussed above.

The settlement provides for a black-box refund of $235 million from System Energy to Entergy Mississippi, which was to be paid within 120 days of the settlement’s effective date (either the date of the FERC approval of the settlement without material modification, or the date that all settling parties agree to accept modifications or otherwise modify the settlement in response to a proposed material modification by the FERC). In addition, beginning with the July 2022 service month, the settlement provides for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates.

The settlement was expressly contingent upon the approval of the FERC and the MPSC. It was approved by the MPSC in June 2022 and the FERC in November 2022. The remaining retail regulators of Entergy’s utility operating company purchasers under the Unit Power Sales Agreement (the APSC, the LPSC, and the City Council) were offered an option to elect to join the settlement, but none of them has elected to do so yet.

System Energy previously recorded a provision and associated liability of $37 million for elements of the applicable litigation. In June 2022, System Energy recorded a regulatory charge of $551 million ($413 million net-of-tax), increasing the regulatory liability to $588 million, which consisted of $235 million for the settlement with the MPSC and $353 million for potential future refunds to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. System Energy paid the black-box refund of $235 million to Entergy Mississippi in November 2022. In addition, as discussed above in “Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue,” $103.5 million of the total remaining regulatory liability of $353 million was reclassified to a current regulatory liability as of December 31, 2022 to reflect the refunds being paid to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans in January 2023 as a result of the FERC’s order in December 2022 on those issues.

Unit Power Sales Agreement

In December 2021, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement to adopt updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses. The proposed amendments would result in higher charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. In February 2022 the FERC accepted System Entergy’s proposed increased depreciation rates with an effective date of March 1, 2022, subject to refund pending the outcome of the settlement and/or hearing procedures. Settlement procedures are ongoing.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. Entergy Mississippi’s storm damage provision balance has been less than $10 million since May 2019, and Entergy Mississippi has been billing the monthly storm damage provision since July 2019.

NOTE 3. INCOME TAXES
Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2022 are as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Federal net operating losses before 1/1/2018
$— billion
$1.2 billion
$— billion
$0.6 billion
$— billion
$— billion
Year(s) of expiration
N/A
2035-2037
N/A
2037
N/A
N/A
Federal net operating losses - 1/1/2018 forward
$4.7 billion
$3.8 billion
$1.9 billion
$0.5 billion
$1.9 billion
$0.1 billion
Year(s) of expiration
N/A
N/A
N/A
N/A
N/A
N/A
State net operating losses
$4.9 billion
$6.5 billion
$2 billion
$1.4 billion
$1 million
$0.2 million
Year(s) of expiration
2023-2031
N/A
2038-2041
N/A
2028
N/A
Misc. federal credits
$7.2 million
$14.1 million
$2.9 million
$15.7 million
$3.2 million
$2.2 million
Year(s) of expiration
2038-2042
2035-2042
2038-2042
2037-2042
2036-2042
2036-2042
State credits
$— million
$— million
$6.8 million
$— million
$2.4 million
$15.5 million
Year(s) of expiration
N/A
N/A
2023-2026
N/A
2027-2032
2023-2026

As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers.

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2022, 2021, and 2020 is as follows:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2022
$1,408,494
$604,628
$549,569
$639,497
$552,295
$23,356
Additions based on tax positions related to the current year (b)
40,502
750,320
185
72
173
690
Additions for tax positions of prior years
6,233
10,262
1,122
393
801
761
Reductions for tax positions of prior years
(2,410)
(14,374)
(3,328)
(1,236)
(163,903)
(1,105)
Gross balance at December 31, 2022
1,452,819
1,350,836
547,548
638,726
389,366
23,702
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(1,277,414)
(1,328,916)
(504,940)
(455,928)
(377,054)
(23,702)
Unrecognized tax benefits net of unused tax attributes
$175,405
$21,920
$42,608
$182,798
$12,312
$—
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2021
$1,364,635
$640,295
$549,717
$639,546
$521,932
$21,652
Additions based on tax positions related to the current year
30,419
13,437
684
1,050
32,616
1,753
Additions for tax positions of prior years
15,013
9,304
1,504
6
2,315
1,897
Reductions for tax positions of prior years
(1,573)
(58,408)
(2,336)
(1,105)
(4,568)
(1,946)
Gross balance at December 31, 2021
1,408,494
604,628
549,569
639,497
552,295
23,356
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(992,643)
(604,628)
(388,728)
(484,899)
(540,694)
(8,576)
Unrecognized tax benefits net of unused tax attributes
$415,851
$—
$160,841
$154,598
$11,601
$14,780
2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Gross balance at January 1, 2020
$1,341,242
$2,381,653
$566,287
$716,773
$21,406
$473,331
Additions based on tax positions related to the current year (a)
9,403
35,681
5,619
2,430
504,362
4,013
Additions for tax positions of prior years
13,400
10,508
1,156
294
799
4,606
Reductions for tax positions of prior years
(11,346)
(679,601)
(24,173)
(80,267)
(5,559)
(41,466)
Settlements
11,936
(1,107,946)
828
316
924
(418,832)
Gross balance at December 31, 2020
1,364,635
640,295
549,717
639,546
521,932
21,652
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers
(1,112,628)
(640,295)
(465,679)
(451,922)
(507,720)
(7,413)
Unrecognized tax benefits net of unused tax attributes
$252,007
$—
$84,038
$187,624
$14,212
$14,239

a.The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “Other Tax Matters - Tax Accounting Methods” below.
b.The primary additions for Entergy Louisiana in 2022 are related to the Entergy Louisiana securitization as discussed in “Other Tax Matters - Act 293 Securitization below.
The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:

December 31,
2022
2021
2020
(In Millions)
Entergy Arkansas
$377.9
$262.1
$259.3
Entergy Louisiana
$720.8
$66.3
$63.8
Entergy Mississippi
$151.2
$51.7
$50.7
Entergy New Orleans
$310.7
$228.6
$203.5
Entergy Texas
$3.3
$2.6
$6.1
System Energy
$2.5
$1.7
$0.5

Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows:
December 31,
2022
2021
2020
(In Millions)
Entergy Arkansas
$4.3
$2.7
$2.3
Entergy Louisiana
$4.1
$3.7
$3.4
Entergy Mississippi
$3.1
$2.4
$1.9
Entergy New Orleans
$6.4
$5.2
$3.9
Entergy Texas
$1.1
$1.1
$0.9
System Energy
$1.9
$12.1
$11.9

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2022, 2021, and 2020. Interest (net-of-tax) was recorded as follows:
2022
2021
2020
(In Millions)
Entergy Arkansas
$1.6
$0.4
($0.8)
Entergy Louisiana
$0.4
$0.3
($10.8)
Entergy Mississippi
$0.7
$0.5
$0.2
Entergy New Orleans
$1.2
$1.3
($0.8)
Entergy Texas
$—
$0.2
($0.2)
System Energy
($10.2)
$0.2
($2.6)

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2014-2015 IRS Audit
The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020.

Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018.

TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020.

The IRS issued final regulations which were effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that its classification as a public utility will continue to apply to its business operations making the application of the interest expense limitation to Entergy unlikely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns.

With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers since 2019 in the form of lower rates. Entergy’s December 31, 2022 and December 31, 2021 balance sheets reflect a regulatory liability of $1.3 billion and $1.3 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers since the enactment of TCJA.
Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2022 and December 31, 2021 balance sheets reflect net regulatory liabilities for income taxes as follows:

2022
2021
(In Millions)
Entergy Arkansas
$435
$432
Entergy Louisiana
$338
$338
Entergy Mississippi
$202
$212
Entergy New Orleans
$40
$42
Entergy Texas
$133
$171
System Energy
$111
$113

Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2022 and December 31, 2021, includes protected excess ADIT as follows:
2022
2021
(In Millions)
Entergy Arkansas
$453
$463
Entergy Louisiana
$675
$669
Entergy Mississippi
$226
$237
Entergy New Orleans
$53
$56
Entergy Texas
$201
$208
System Energy
$137
$148

Entergy anticipates that the effect of TCJA may continue to have ramifications that require adjustments in the future as certain events occur. These events include: 1) IRS audit adjustments to or amendments of federal and state income tax returns that include modifications to the computation of taxable income resulting from TCJA; and 2) additional guidance, interpretations, or rulings by the U.S. Department of the Treasury or the IRS. The potential exists for these types of events to result in future tax expense adjustments because of the difference in the federal corporate income tax rate between past and future periods and the effect of the tax rate change on ratemaking. In turn, these events also could potentially affect the regulatory liability for income taxes.

Coronavirus Aid, Relief, and Economic Security Act

In response to the economic impacts of the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) into law on March 27, 2020. The CARES Act provisions that result in the most significant opportunities for tax relief to Entergy and the Registrant Subsidiaries are (i) permitting a five-year carryback of 2018-2020 NOLs, (ii) removing the 80 percent limitation on NOLs carried to tax years beginning before 2021, (iii) increasing the limitation on interest expense deductibility for 2019 and 2020, (iv) accelerating available refunds for minimum tax credit carryforwards, modifying limitations on charitable contributions during 2020, and (v) delaying the payment of employer payroll taxes. Entergy deferred approximately $64 million of 2020 payroll tax payments, payable in equal installments over two years. The initial installment of $32 million was paid in December 2021. The second installment of $32 million was paid in December 2022.

Inflation Reduction Act of 2022

The Inflation Reduction Act of 2022, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and
certain qualified nuclear power plants. Additionally, the Inflation Reduction Act of 2022 enacted a 1% excise tax on the buyback of public company stock and a new corporate alternative minimum tax. There are no effects on the financial statements as of and for the year ended December 31, 2022 related to the enactment of the law. See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for additional discussion of the effects of the Inflation Reduction Act of 2022.

Tax Accounting Methods

In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement. The election resulted in a $2.2 billion deductible temporary difference. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for wholesale electric contracts which resulted in a $1.1 billion deductible temporary difference. In 2018, Entergy Arkansas and Entergy Mississippi accrued deductible temporary differences related to mark-to-market tax accounting for wholesale electric contracts of $2.1 billion and $1.9 billion, respectively. Additionally, in 2020, Entergy Texas elected mark-to-market income tax treatment for wholesale electric power purchase and sale agreements which resulted in a $2.5 billion deductible temporary difference.

Stock Compensation

In accordance with stock compensation accounting rules, Entergy and the Registrant Subsidiaries recognized excess tax deductions as a reduction of income tax expense in the first quarter 2020. Due to the vesting and exercise of certain Entergy stock-based awards, Entergy recorded a permanent tax reduction of approximately $24.7 million, including $4.8 million for Entergy Arkansas, $8.6 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $2.7 million for Entergy Texas, and $1.3 million for System Energy.



NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2022 as follows:
Company
Expiration Date
Amount of Facility
Interest Rate (a)
Amount Drawn
as of
December 31, 2022
Letters of Credit Outstanding as of December 31, 2022
Entergy Arkansas
April 2023
$25 million (b)
5.98%
Entergy Arkansas
June 2027
$150 million (c)
5.55%
Entergy Louisiana
June 2027
$350 million (c)
7.75%
$50 million
Entergy Mississippi
April 2023
$45 million (d)
5.92%
Entergy Mississippi
April 2023
$40 million (d)
5.92%
Entergy Mississippi
April 2023
$10 million (d)
5.92%
Entergy Mississippi
July 2024
$150 million
5.55%
Entergy New Orleans
June 2024
$25 million (c)
6.01%
Entergy Texas
June 2027
$150 million (c)
5.67%
$1.1 million
a.The interest rate is the estimated interest rate as of December 31, 2022 that would have been applied to outstanding borrowings under the facility.
b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
d.Borrowings under the short-term Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the MISO uncommitted standby letter of credit facilities as of December 31, 2022:
Company
Amount of Uncommitted Facility
Letter of Credit Fee
Letters of Credit Issued as of
December 31, 2022
(a) (b)
Entergy Arkansas
$25 million
0.78%
$5.6 million
Entergy Louisiana
$125 million
0.78%
$20.0 million
Entergy Mississippi
$65 million
0.78%
$6.7 million
Entergy New Orleans
$15 million
1.625%
$1.0 million
Entergy Texas
$80 million
0.875%
$34.8 million

a.As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.
b.As of December 31, 2022, in addition to the $6.7 million MISO letter of credit, Entergy Mississippi has $1.0 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2022 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
Authorized
Borrowings
(In Millions)
Entergy Arkansas
$250
$181
Entergy Louisiana
$450
$226
Entergy Mississippi
$200
$—
Entergy New Orleans
$150
$—
Entergy Texas
$200
$—
System Energy
$200
$—


NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257.

Entergy Mississippi has obtained long-term financing authorizations from the FERC that extend through October 2023.


NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTERESTS

Note 6 to the financial statements is not applicable to Entergy Mississippi.

NOTE 7. COMMON EQUITY

Note 7 to the financial statements is not applicable to Entergy Mississippi.

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers.
For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies.


Grand Gulf - Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2022 under the agreement were approximately $19.8 million for Entergy Arkansas, $7.8 million for Entergy Louisiana, $17.7 million for Entergy Mississippi, and $9.5 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and
expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated (Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.


NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2022 and 2021 by the Registrant Subsidiaries were as follows:
Liabilities as
of December 31,
2021


Accretion
Change in
Cash Flow
Estimate


Spending
Dispositions
Liabilities as
of December 31,
2022
(In Millions)
Utility
Entergy Arkansas
$1,390.4
$82.3
$—
$—
$—
$1,472.7
Entergy Louisiana
$1,653.2
$84.1
$2.8
($3.3)
$—
$1,736.8
Entergy Mississippi
$10.3
$0.6
$—
($3.1)
$—
$7.8
Entergy New Orleans
$4.0
$0.1
$—
($4.1)
$—
$—
Entergy Texas
$8.5
$0.5
$2.1
$—
$—
$11.1
System Energy
$1,007.6
$40.2
($5.4)
$—
$—
$1,042.5
Liabilities as
of December 31,
2020


Accretion


Spending
Dispositions
Liabilities as
of December 31,
2021
(In Millions)
Utility
Entergy Arkansas
$1,314.2
$77.7
$—
($1.5)
$1,390.4
Entergy Louisiana
$1,573.3
$79.9
$—
$—
$1,653.2
Entergy Mississippi
$9.8
$0.5
$—
$—
$10.3
Entergy New Orleans
$3.8
$0.2
$—
$—
$4.0
Entergy Texas
$8.1
$0.4
$—
$—
$8.5
System Energy
$968.9
$38.7
$—
$—
$1,007.6

Coal Combustion Residuals

In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.


NOTE 10. LEASES
As of December 31, 2022 and 2021, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards.

Leases have remaining terms of one year to 58 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy
New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$15,435
$15,016
$7,510
$1,755
$5,624
Finance lease cost:
Amortization of right-of-use assets
$3,048
$4,259
$1,962
$906
$1,629
Interest on lease liabilities
$402
$592
$261
$134
$230

Of the lease costs disclosed above, Entergy Mississippi had $0.9 million in short-term lease costs for the year ended December 31, 2022.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy
New Orleans
Entergy Texas
(In Thousands)
Operating lease cost
$15,087
$14,368
$7,018
$1,745
$5,370
Finance lease cost:
Amortization of right-of-use assets
$2,860
$3,938
$1,766
$731
$1,493
Interest on lease liabilities
$432
$607
$270
$124
$214

Of the lease costs disclosed above, Entergy Mississippi had $703 thousand in short-term lease costs for the year ended December 31, 2021.

The lease costs for the years ended December 31, 2022 and 2021 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.
Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022 and 2021 are the following amounts:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
Operating leases
$56,000
$46,137
$23,624
$5,906
$17,076
Finance leases
$13,493
$18,540
$8,578
$4,342
$8,094
2021
Operating leases
$56,099
$46,443
$16,831
$5,480
$14,986
Finance leases
$15,043
$19,007
$9,114
$4,023
$7,583

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$14,140
$13,554
$6,540
$1,650
$5,640
Finance leases
$2,985
$4,276
$1,974
$918
$1,654
Non-current liabilities:
Operating leases
$41,874
$32,588
$17,098
$4,217
$11,441
Finance leases
$10,508
$14,264
$6,604
$3,424
$6,440

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities:
Operating leases
$12,695
$12,520
$5,866
$1,491
$4,489
Finance leases
$2,964
$4,001
$1,843
$812
$1,476
Non-current liabilities:
Operating leases
$43,420
$33,931
$10,976
$3,994
$10,505
Finance leases
$12,079
$15,006
$7,271
$3,211
$6,107
The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted average remaining lease terms:
Operating leases
4.55
4.26
5.31
6.08
3.84
Finance leases
5.32
5.27
5.15
5.72
5.67
Weighted average discount rate:
Operating leases
3.43
3.24
3.52
3.50
3.63
Finance leases
2.93
3.15
2.87
3.04
3.07

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Weighted average remaining lease terms:
Operating leases
5.13
4.65
5.36
5.35
3.94
Finance leases
5.89
5.57
5.63
5.94
5.97
Weighted average discount rate:
Operating leases
3.10
2.93
3.00
2.99
3.04
Finance leases
2.80
3.08
2.87
3.03
2.79


Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2022 are as follows:

Operating Leases
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$15,754
$14,808
$7,230
$1,801
$6,152
2024
14,195
12,656
6,244
1,569
5,080
2025
12,359
9,779
5,319
1,116
3,621
2026
9,578
6,195
3,224
684
1,930
2027
6,285
3,556
1,867
305
895
Years thereafter
2,242
2,278
2,328
1,113
615
Minimum lease payments
60,413
49,272
26,212
6,588
18,293
Less: amount representing interest
4,399
3,129
2,574
722
1,212
Present value of net minimum lease payments
$56,014
$46,143
$23,638
$5,866
$17,081
Finance Leases
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2023
$3,334
$4,791
$2,191
$1,036
$1,875
2024
3,034
4,246
2,007
906
1,719
2025
2,693
3,703
1,748
795
1,588
2026
2,253
2,942
1,414
718
1,341
2027
1,656
2,112
962
585
1,034
Years thereafter
1,526
2,239
856
667
1,231
Minimum lease payments
14,496
20,033
9,178
4,707
8,788
Less: amount representing interest
1,002
1,493
600
365
694
Present value of net minimum lease payments
$13,494
$18,540
$8,578
$4,342
$8,094

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has seven defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees, the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in the plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature.
The assets of the seven defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

The Registrant Subsidiaries’ total 2022, 2021, and 2020 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$25,210
$33,520
$8,043
$2,745
$5,999
$7,746
Interest cost on projected benefit obligation
45,378
49,330
12,979
5,491
10,729
11,286
Expected return on assets
(75,820)
(82,478)
(20,168)
(9,920)
(18,317)
(18,173)
Recognized net loss
43,597
41,711
12,594
4,787
9,013
10,938
Settlement charges
36,409
58,550
15,786
6,676
22,411
9,905
Net pension cost
$74,774
$100,633
$29,234
$9,779
$29,835
$21,702
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net (gain)/loss
$28,365
($15,604)
($4,743)
$525
$13,363
($7,063)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(43,597)
(41,711)
(12,594)
(4,787)
(9,013)
(10,938)
Settlement charge
(36,409)
(58,550)
(15,786)
(6,676)
(22,411)
(9,905)
Total
($51,641)
($115,865)
($33,123)
($10,938)
($18,061)
($27,906)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
$23,133
($15,232)
($3,889)
($1,159)
$11,774
($6,204)
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$28,632
$38,271
$9,070
$3,038
$6,921
$8,851
Interest cost on projected benefit obligation
35,683
39,740
10,446
4,392
8,381
9,087
Expected return on assets
(78,368)
(89,821)
(22,407)
(10,598)
(21,158)
(19,254)
Recognized net loss
69,290
67,015
20,007
7,596
12,676
18,404
Settlement charges
37,682
61,945
16,710
5,431
11,797
12,260
Net pension cost
$92,919
$117,150
$33,826
$9,859
$18,617
$29,348
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain
($96,066)
($89,534)
($29,675)
($16,159)
($18,217)
($27,617)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(69,290)
(67,015)
(20,007)
(7,596)
(12,676)
(18,404)
Settlement charge
(37,682)
(61,945)
(16,710)
(5,431)
(11,797)
(12,260)
Total
($203,038)
($218,494)
($66,392)
($29,186)
($42,690)
($58,281)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
($110,119)
($101,344)
($32,566)
($19,327)
($24,073)
($28,933)
2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period
$26,329
$35,158
$8,060
$2,654
$6,116
$7,883
Interest cost on projected benefit obligation
44,165
50,432
12,922
5,825
10,731
11,006
Expected return on assets
(78,187)
(89,691)
(23,147)
(10,509)
(21,951)
(18,757)
Recognized net loss
68,338
66,640
18,983
8,018
13,173
17,104
Settlement charges
21,078
8,109
3,366
4,289
105
Net pension cost
$81,723
$70,648
$20,184
$5,988
$12,358
$17,341
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss
$106,178
$90,064
$36,899
$8,148
$13,379
$35,403
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss
(69,713)
(68,248)
(19,393)
(8,213)
(13,564)
(17,434)
Settlement charge
(21,078)
(8,109)
(3,366)
(4,289)
(105)
Total
$15,387
$13,707
$14,140
($65)
($4,474)
$17,864
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)
$97,110
$84,355
$34,324
$5,923
$7,884
$35,205

Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2022 and 2021 are as follows:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,579,346
$1,736,396
$448,858
$195,380
$371,802
$394,794
Service cost
25,210
33,520
8,043
2,745
5,999
7,746
Interest cost
45,378
49,330
12,979
5,491
10,729
11,286
Actuarial gain
(280,691)
(357,572)
(88,303)
(40,462)
(65,795)
(81,504)
Benefits paid (a)
(201,145)
(205,252)
(60,583)
(22,718)
(57,170)
(44,020)
Balance at December 31
$1,168,098
$1,256,422
$320,994
$140,436
$265,565
$288,302
Change in Plan Assets
Fair value of assets at January
$1,302,588
$1,446,658
$356,424
$172,366
$341,915
$312,060
Actual return on plan assets
(233,236)
(259,490)
(63,392)
(31,067)
(60,841)
(56,267)
Employer contributions
92,971
53,658
33,287
1,129
2,513
28,619
Benefits paid (a)
(201,145)
(205,252)
(60,583)
(22,718)
(57,170)
(44,020)
Fair value of assets at December 31
$961,178
$1,035,574
$265,736
$119,710
$226,417
$240,392
Funded status
($206,920)
($220,848)
($55,258)
($20,726)
($39,148)
($47,910)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($206,920)
($220,848)
($55,258)
($20,726)
($39,148)
($47,910)
Amounts recognized as regulatory asset
Net loss
$561,323
$445,116
$140,389
$51,868
$95,729
$125,876
Amounts recognized as AOCI (before tax)
Net loss
$—
$18,546
$—
$—
$—
$—

(a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy.
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1
$1,739,382
$1,927,271
$510,109
$220,287
$410,664
$441,148
Service cost
28,632
38,271
9,070
3,038
6,921
8,851
Interest cost
35,683
39,740
10,446
4,392
8,381
9,087
Actuarial gain
(41,227)
(28,439)
(14,831)
(9,118)
(3,971)
(14,746)
Benefits paid (a)
(183,124)
(240,447)
(65,936)
(23,219)
(50,193)
(49,546)
Balance at December 31
$1,579,346
$1,736,396
$448,858
$195,380
$371,802
$394,794
Change in Plan Assets
Fair value of assets at January
$1,285,856
$1,476,306
$371,394
$172,551
$349,748
$310,818
Actual return on plan assets
133,207
150,917
37,251
17,639
35,405
32,125
Employer contributions
66,649
59,882
13,715
5,395
6,955
18,663
Benefits paid (a)
(183,124)
(240,447)
(65,936)
(23,219)
(50,193)
(49,546)
Fair value of assets at December 31
$1,302,588
$1,446,658
$356,424
$172,366
$341,915
$312,060
Funded status
($276,758)
($289,738)
($92,434)
($23,014)
($29,887)
($82,734)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities
($276,758)
($289,738)
($92,434)
($23,014)
($29,887)
($82,734)
Amounts recognized as regulatory asset
Net loss
$612,963
$556,345
$173,511
$62,805
$113,790
$153,782
Amounts recognized as AOCI (before tax)
Net loss
$—
$23,181
$—
$—
$—
$—

(a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy.
The qualified pension plans incurred a small actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021.

Accumulated Pension Benefit Obligation

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2022 and 2021 was as follows:
December 31,
2022
2021
(In Thousands)
Entergy Arkansas
$1,008,152
$1,463,966
Entergy Louisiana
$1,146,561
$1,574,273
Entergy Mississippi
$292,596
$407,851
Entergy New Orleans
$128,499
$178,010
Entergy Texas
$245,428
$342,441
System Energy
$269,583
$366,920

Other Postretirement Benefits

Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law.

Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy
Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf.

Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts.

Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI

Total 2022, 2021, and 2020 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Other postretirement costs:
Service cost - benefits earned during the period
$4,457
$5,633
$1,354
$397
$1,322
$1,239
Interest cost on APBO
5,050
5,770
1,401
694
1,596
1,116
Expected return on assets
(17,930)
(5,575)
(5,997)
(10,273)
(3,162)
Amortization of prior service cost/(credit)
1,885
(4,630)
(1,772)
(916)
(4,371)
(319)
Recognized net (gain)/ loss
873
(744)
222
(898)
648
121
Net other postretirement benefit (income)/cost
($5,665)
$6,029
($4,370)
($6,720)
($11,078)
($1,005)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
$273
$323
($1,300)
$—
$—
$141
Net (gain)/loss
12,894
(65,501)
6,629
17,334
22,323
1,208
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit/(cost)
(1,885)
4,630
1,772
916
4,371
319
Amortization of net (gain)/loss
(873)
744
(222)
898
(648)
(121)
Total
$10,409
($59,804)
$6,879
$19,148
$26,046
$1,547
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
$4,744
($53,775)
$2,509
$12,428
$14,968
$542
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$4,135
$6,174
$1,448
$437
$1,384
$1,340
Interest cost on APBO
3,726
4,520
1,110
521
1,269
878
Expected return on assets
(18,020)
(5,536)
(5,750)
(10,192)
(3,156)
Amortization of prior service credit
(1,121)
(4,920)
(1,775)
(916)
(3,742)
(436)
Recognized net (gain)/loss
196
(364)
76
(712)
398
61
Net other postretirement benefit (income)/cost
($11,084)
$5,410
($4,677)
($6,420)
($10,883)
($1,313)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
($85)
$357
$—
$—
($3,776)
$69
Net (gain)/loss
9,956
(2,367)
(2,823)
(3,330)
939
210
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
1,121
4,920
1,775
916
3,742
436
Amortization of net (gain)/ loss
(196)
364
(76)
712
(398)
(61)
Total
$10,796
$3,274
($1,124)
($1,702)
$507
$654
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
($288)
$8,684
($5,801)
($8,122)
($10,376)
($659)
2020
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period
$3,626
$5,993
$1,468
$445
$1,219
$1,254
Interest cost on APBO
4,712
6,216
1,536
784
2,008
1,130
Expected return on assets
(17,104)
(5,167)
(5,382)
(9,643)
(2,958)
Amortization of prior service credit
(1,849)
(6,179)
(1,652)
(763)
(3,364)
(1,065)
Recognized net (gain)/loss
540
(447)
171
(13)
907
121
Net other postretirement benefit (income)/cost
($10,075)
$5,583
($3,644)
($4,929)
($8,873)
($1,518)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period
$12,320
($23,508)
($4,428)
($5,493)
($22,441)
($1,963)
Net (gain)/loss
2,245
8,744
(4,456)
(5,351)
(3,266)
58
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit
1,849
6,179
1,652
763
3,364
1,065
Amortization of net (gain)/loss
(540)
447
(171)
13
(907)
(121)
Total
$15,874
($8,138)
($7,403)
($10,068)
($23,250)
($961)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)
$5,799
($2,555)
($11,047)
($14,997)
($32,123)
($2,479)

Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet

Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2022 and 2021 are as follows:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$221,183
$253,031
$61,001
$31,866
$71,961
$47,875
Service cost
4,457
5,633
1,354
397
1,322
1,239
Interest cost
5,050
5,770
1,401
694
1,596
1,116
Plan amendments
273
323
(1,300)
141
Plan participant contributions
5,521
5,081
1,443
440
924
1,222
Actuarial gain
(54,923)
(65,501)
(14,465)
(6,867)
(16,291)
(10,679)
Benefits paid
(17,585)
(21,268)
(5,075)
(2,566)
(6,046)
(5,657)
Medicare Part D subsidy received
42
57
6
7
16
17
Balance at December 31
$164,018
$183,126
$44,365
$23,971
$53,482
$35,274
Change in Plan Assets
Fair value of assets at January 1
$315,495
$—
$97,888
$111,137
$182,285
$54,650
Actual return on plan assets
(49,887)
(15,519)
(18,204)
(28,341)
(8,725)
Employer contributions
1,573
16,187
759
333
(23)
944
Plan participant contributions
5,521
5,081
1,443
440
924
1,222
Benefits paid
(17,585)
(21,268)
(5,075)
(2,566)
(6,046)
(5,657)
Fair value of assets at December 31
$255,117
$—
$79,496
$91,140
$148,799
$42,434
Funded status
$91,099
($183,126)
$35,131
$67,169
$95,317
$7,160
Amounts recognized in the balance sheet
Current liabilities
$—
($15,356)
$—
$—
$—
$—
Non-current liabilities
91,099
(167,770)
35,131
67,169
95,317
7,160
Total funded status
$91,099
($183,126)
$35,131
$67,169
$95,317
$7,160
Amounts recognized in regulatory asset
Prior service cost/(credit)
$7,079
$—
($3,637)
($2,898)
($16,161)
($789)
Net loss
5,224
2,153
2,229
24,246
4,054
$12,303
$—
($1,484)
($669)
$8,085
$3,265
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($12,015)
$—
$—
$—
$—
Net gain
(82,308)
$—
($94,323)
$—
$—
$—
$—
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Change in APBO
Balance at January 1
$209,369
$255,571
$61,990
$31,707
$74,233
$47,701
Service cost
4,135
6,174
1,448
437
1,384
1,340
Interest cost
3,726
4,520
1,110
521
1,269
878
Plan amendments
(85)
357
(3,776)
69
Plan participant contributions
5,637
5,186
1,386
403
1,491
1,353
Actuarial (gain)/loss
14,323
(2,367)
(1,335)
988
4,270
1,289
Benefits paid
(15,954)
(16,460)
(3,604)
(2,194)
(6,923)
(4,769)
Medicare Part D subsidy received
32
50
6
4
13
14
Balance at December 31
$221,183
$253,031
$61,001
$31,866
$71,961
$47,875
Change in Plan Assets
Fair value of assets at January 1
$304,192
$—
$93,475
$102,734
$174,096
$52,619
Actual return on plan assets
22,387
7,024
10,068
13,523
4,235
Employer contributions
(767)
11,274
(393)
126
98
1,212
Plan participant contributions
5,637
5,186
1,386
403
1,491
1,353
Benefits paid
(15,954)
(16,460)
(3,604)
(2,194)
(6,923)
(4,769)
Fair value of assets at December 31
$315,495
$—
$97,888
$111,137
$182,285
$54,650
Funded status
$94,312
($253,031)
$36,887
$79,271
$110,324
$6,775
Amounts recognized in the balance sheet
Current liabilities
$—
($15,839)
$—
$—
$—
$—
Non-current liabilities
94,312
(237,192)
36,887
79,271
110,324
6,775
Total funded status
$94,312
($253,031)
$36,887
$79,271
$110,324
$6,775
Amounts recognized in regulatory asset
Prior service cost/(credit)
$8,691
$—
($4,109)
($3,814)
($20,532)
($1,249)
Net (gain)/loss
(6,797)
(4,254)
(16,003)
2,571
2,967
$1,894
$—
($8,363)
($19,817)
($17,961)
$1,718
Amounts recognized in AOCI (before tax)
Prior service credit
$—
($16,967)
$—
$—
$—
$—
Net gain
(17,551)
$—
($34,518)
$—
$—
$—
$—

The other postretirement plans incurred actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations.

Non-Qualified Pension Plans

Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees.

The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2022, 2021, and 2020, was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$282
$102
$321
$114
$1,320
2021
$343
$307
$365
$30
$615
2020
$333
$148
$359
$31
$469

Included in the 2022 net periodic pension cost above are settlement charges of $1 thousand, $2 thousand, and $1 million for Entergy Louisiana, Entergy Mississippi, and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included in the 2021 net periodic pension cost above are settlement charges of $155 thousand and $172 thousand for Entergy Louisiana and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2022 and 2021 was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$2,433
$1,197
$3,830
$1,024
$3,850
2021
$2,875
$1,469
$3,708
$1,069
$7,462

The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2022 and 2021 was as follows:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$2,192
$1,197
$3,594
$719
$3,776
2021
$2,482
$1,445
$3,377
$738
$7,355

The following amounts were recorded on the balance sheet as of December 31, 2022 and 2021:
2022
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($234)
($184)
($214)
($32)
($448)
Non-current liabilities
(2,199)
(1,013)
(3,616)
(992)
(3,402)
Total funded status
($2,433)
($1,197)
($3,830)
($1,024)
($3,850)
Regulatory asset/(liability)
$512
$119
$1,291
$111
($2,615)
Accumulated other comprehensive income (before taxes)
$—
$5
$—
$—
$—
2021
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Current liabilities
($248)
($186)
($190)
($31)
($3,080)
Non-current liabilities
(2,627)
(1,283)
(3,518)
(1,039)
(4,382)
Total funded status
($2,875)
($1,469)
($3,708)
($1,070)
($7,462)
Regulatory asset/(liability)
$1,059
$233
$1,368
$251
($706)
Accumulated other comprehensive income (before taxes)
$—
$10
$—
$—
$—

The non-qualified pension plans incurred a small actuarial gain during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by differences in recent retirement and lump sum experience relative to actuarial assumptions. The non-qualified pension plans incurred actuarial losses during 2021 primarily due to differences in recent retirement and lump sum experience relative to actuarial assumptions.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from Non-Bargaining I, Bargaining I, Non-Bargaining II, and Bargaining II exceeded the sum of the Plans’ 2022 service and interest cost, resulting in settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of Non-Bargaining I and Bargaining I and incurred settlement costs. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Qualified Pension and Other Postretirement Plans’ Assets

The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.

In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period.

The target asset allocation for pension adjusts dynamically based on the pension plans’ funded status. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets.
For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts.

Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2022 and 2021 and the target asset allocation and ranges for 2022 are as follows:
Pension Asset Allocation
Target
Range
Actual 2022
Actual 2021
Domestic Equity Securities
43%
35%
to
51%
42%
40%
International Equity Securities
22%
17%
to
27%
22%
20%
Fixed Income Securities
35%
29%
to
41%
33%
40%
Other
—%
—%
to
10%
3%
—%
Postretirement Asset Allocation
Non-Taxable and Taxable
Target
Range
Actual 2022
Actual 2021
Domestic Equity Securities
25%
20%
to
30%
25%
28%
International Equity Securities
17%
12%
to
22%
18%
17%
Fixed Income Securities
58%
53%
to
63%
57%
55%
Other
—%
—%
to
5%
—%
—%

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers.

The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades.

The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used.

For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets.

Concentrations of Credit Risk

Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area, and individual security issuance. As of December 31, 2022, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefit plan assets.

Fair Value Measurements
Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are described below:

Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

- quoted prices for similar assets or liabilities in active markets;
- quoted prices for identical assets or liabilities in inactive markets;
- inputs other than quoted prices that are observable for the asset or liability; or
- inputs that are derived principally from or corroborated by observable market data by correlation or other means.

If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.

Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2022, and December 31, 2021, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.

Qualified Defined Benefit Pension Plan Trusts
2022
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$12,178
(b)
$—
$—
$12,178
Common
807,437
(b)
807,437
Common collective trusts (c)
2,516,688
Fixed income securities:
U.S. Government securities
673,348
(a)
673,348
Corporate debt instruments
525,184
(a)
525,184
Registered investment companies (e)
221,582
(d)
2,595
(d)
750,454
Other
15,395
(f)
15,395
Other:
Insurance company general account (unallocated contracts)
5,911
(g)
5,911
Total investments
$1,041,197
$1,222,433
$—
$5,306,595
Cash
10,601
Other pending transactions
(13,813)
Less: Other postretirement assets included in total investments
(61,285)
Total fair value of qualified pension assets
$5,242,098
2021
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Corporate stocks:
Preferred
$16,231
(b)
$—
$—
$16,231
Common
1,001,169
(b)
1,001,169
Common collective trusts (c)
3,123,111
Fixed income securities:
U.S. Government securities
627,148
(a)
627,148
Corporate debt instruments
966,616
(a)
966,616
Registered investment companies (e)
92,347
(d)
3,004
(d)
1,129,070
Other
68,886
(f)
68,886
Other:
Insurance company general account (unallocated contracts)
5,961
(g)
5,961
Total investments
$1,109,747
$1,671,615
$—
$6,938,192
Cash
123,153
Other pending transactions
11,125
Less: Other postretirement assets included in total investments
(79,360)
Total fair value of qualified pension assets
$6,993,110

Other Postretirement Trusts
2022
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$241,676
Fixed income securities:
U.S. Government securities
$69,503
(b)
$78,436
(a)
$—
147,939
Corporate debt instruments
113,273
(a)
113,273
Registered investment companies
3,016
(d)
3,016
Other
56,149
(f)
56,149
Total investments
$72,519
$247,858
$—
$562,053
Other pending transactions
486
Plus: Other postretirement assets included in the investments of the qualified pension trust
61,285
Total fair value of other postretirement assets
$623,824
2021
Level 1
Level 2
Level 3
Total
(In Thousands)
Equity securities:
Common collective trust (c)
$312,594
Fixed income securities:
U.S. Government securities
$62,240
(b)
$89,951
(a)
$—
152,191
Corporate debt instruments
152,562
(a)
152,562
Registered investment companies
28,450
(d)
28,450
Other
72,059
(f)
72,059
Total investments
$90,690
$314,572
$—
$717,856
Other pending transactions
(25,897)
Plus: Other postretirement assets included in the investments of the qualified pension trust
79,360
Total fair value of other postretirement assets
$771,319

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.
b.Common stocks, preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.
c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities valued at the daily closing price as reported by the fund. These funds are required to publish their daily net asset value and to transact at that price. The money market mutual funds held by the trusts are deemed to be actively traded.
e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.
f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes.
g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Estimated Future Benefit Payments

Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefit obligations at December 31, 2022, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows:
Estimated Future Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2023
$98,261
$105,305
$28,225
$11,840
$25,729
$24,074
2024
$95,703
$103,873
$28,264
$11,755
$24,583
$23,426
2025
$94,960
$103,698
$27,801
$11,411
$23,773
$22,788
2026
$93,958
$102,623
$27,925
$11,549
$24,074
$22,501
2027
$93,116
$100,787
$27,421
$11,177
$22,393
$23,352
2028 - 2032
$454,624
$486,551
$128,050
$52,741
$102,864
$112,550
Estimated Future Non-Qualified Pension Benefits Payments
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
Year(s)
2023
$234
$184
$214
$32
$448
2024
$357
$170
$644
$112
$426
2025
$735
$156
$653
$150
$403
2026
$150
$142
$539
$145
$430
2027
$138
$129
$878
$233
$380
2028 - 2032
$968
$461
$1,605
$690
$1,566
Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy)
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2023
$13,725
$15,361
$3,434
$2,353
$4,931
$2,814
2024
$13,330
$14,837
$3,310
$2,255
$4,723
$2,693
2025
$12,788
$14,519
$3,326
$2,164
$4,581
$2,605
2026
$12,398
$14,108
$3,305
$2,041
$4,340
$2,439
2027
$12,042
$13,720
$3,290
$1,933
$4,232
$2,366
2028 - 2032
$58,491
$64,023
$16,332
$8,375
$19,315
$11,998
Estimated Future Medicare Part D Subsidy
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Year(s)
2023
$1
$5
$12
$—
$—
$1
2024
$—
$5
$1
$1
$—
$—
2025
$—
$—
$—
$—
$—
$—
2026
$—
$—
$—
$—
$—
$—
2027
$—
$—
$—
$—
$—
$—
2028 - 2032
$—
$—
($1)
($1)
$1
$1

Contributions

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2023:
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Thousands)
Pension Contributions
$54,464
$44,561
$21,109
$1,418
$5,317
$15,542
Other Postretirement Contributions
$526
$15,361
$136
$193
$86
$26

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2022 and 2021 were as follows:
2022
2021
Weighted-average discount rate:
Qualified pension
5.21% - 5.27% Blended 5.24%
2.99% - 3.08% Blended 3.05%
Other postretirement
5.20%
2.94%
Non-qualified pension
4.98%
2.11%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
Interest crediting rate
4.00%
2.60%
Assumed health care trend rate:
Pre-65
6.65%
5.65%
Post-65
7.50%
5.90%
Ultimate rate
4.75%
4.75%
Year ultimate rate is reached and beyond:
Pre-65
2032
2032
Post-65
2032
2032

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2022, 2021, and 2020 were as follows:
2022
2021
2020
Weighted-average discount rate:
Qualified pension:
Service cost
3.07%
2.81%
3.42%
Interest cost
2.49%
2.08%
2.99%
Other postretirement:
Service cost
3.20%
2.98%
3.27%
Interest cost
2.31%
1.86%
2.41%
Non-qualified pension:
Service cost
4.94%
1.48%
2.71%
Interest cost
5.03%
2.14%
2.25%
Weighted-average rate of increase in future compensation levels
3.98% - 4.40%
3.98% - 4.40%
3.98% - 4.40%
Expected long-term rate of return on plan assets:
Pension assets
6.75%
6.75%
7.00%
Other postretirement non-taxable assets
5.75% - 6.75%
6.00% - 6.75%
6.25% - 7.25%
Other postretirement taxable assets
4.75%
5.00%
5.25%
Assumed health care trend rate:
Pre-65
5.65%
5.87%
6.13%
Post-65
5.90%
6.31%
6.25%
Ultimate rate
4.75%
4.75%
4.75%
Year ultimate rate is reached and beyond:
Pre-65
2032
2030
2027
Post-65
2032
2028
2027

With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 and 2021 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 and 2021 other postretirement benefit APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which
company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’ basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

The Registrant Subsidiaries’ 2022, 2021, and 2020 contributions to defined contribution plans for their employees were as follows:


Year
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Thousands)
2022
$5,124
$7,138
$3,194
$1,223
$2,938
2021
$4,820
$6,678
$3,045
$1,140
$2,699
2020
$4,515
$6,518
$2,863
$1,115
$2,596


NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.


NOTE 14. ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS

Acquisitions

Sunflower Solar

In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the
terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. Pending the remediation of certain operational issues, final payment is expected in first quarter 2023.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.
Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2022 is 1.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2022 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2022 is 22,811,760 MMBtu for Entergy, including 9,120,000 MMBtu for Entergy Louisiana, 13,088,700 MMBtu for Entergy Mississippi, and 603,060 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2022, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2022 through May 31, 2023. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2022 is 60,163 GWh for Entergy, including 13,532 GWh for Entergy Arkansas, 27,264 GWh for Entergy Louisiana, 6,492 GWh for Entergy Mississippi, 2,596 GWh for Entergy New Orleans, and 10,202 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2022 and 2021. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022 and for Entergy Mississippi and Entergy Texas as of December 31, 2021.
The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2022 and 2021 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
(In Millions)
2022
Assets:
Natural gas swaps and options
Prepayments and other
$13.1
$—
$13.1
Entergy Louisiana
Natural gas swaps and options
Other deferred debits and other assets
$3.4
$—
$3.4
Entergy Louisiana
Financial transmission rights
Prepayments and other
$10.3
$—
$10.3
Entergy Arkansas
Financial transmission rights
Prepayments and other
$7.7
($0.4)
$7.3
Entergy Louisiana
Financial transmission rights
Prepayments and other
$0.6
$—
$0.6
Entergy Mississippi
Financial transmission rights
Prepayments and other
$0.8
$—
$0.8
Entergy New Orleans
Financial transmission rights
Prepayments and other
$1.2
($1.1)
$0.1
Entergy Texas
Liabilities:
Natural gas swaps
Other current liabilities
$24.0
$—
$24.0
Entergy Mississippi
Natural gas swaps
Other current liabilities
$1.5
$—
$1.5
Entergy New Orleans
Instrument
Balance Sheet Location
Gross Fair Value (a)
Offsetting Position (b)
Net Fair Value (c) (d)
Registrant
(In Millions)
2021
Assets:
Natural gas swaps and options
Prepayments and other
$5.7
$—
$5.7
Entergy Louisiana
Natural gas swaps and options
Other deferred debits and other assets
$5.3
$—
$5.3
Entergy Louisiana
Financial transmission rights
Prepayments and other
$2.3
$—
$2.3
Entergy Arkansas
Financial transmission rights
Prepayments and other
$0.6
$—
$0.6
Entergy Louisiana
Financial transmission rights
Prepayments and other
$0.3
$—
$0.3
Entergy Mississippi
Financial transmission rights
Prepayments and other
$0.1
$—
$0.1
Entergy New Orleans
Financial transmission rights
Prepayments and other
$0.8
$—
$0.8
Entergy Texas
Liabilities:
Natural gas swaps
Other current liabilities
$6.7
$—
$6.7
Entergy Mississippi
Natural gas swaps
Other current liabilities
$0.5
$—
$0.5
Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities
b.Represents the netting of fair value balances with the same counterparty
c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
d.As of December 31, 2022 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. As of December 31, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2022, 2021, and 2020 are as follows:
Instrument
Income Statement Location
Amount of gain (loss) recorded in the income statement
Registrant
(In Millions)
2022
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
$21.4
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
$53.6
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($1.2)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power
$106.5
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$48.5
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$10.4
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$3.7
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$6.3
(b)
Entergy Texas
2021
Natural gas swaps and options
Fuel, fuel-related expenses, and gas purchased for resale
$12.6
(a)
Entergy Louisiana
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
$19.8
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($0.1)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power
$42.6
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$31.6
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$11.3
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$4.3
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$85.9
(b)
Entergy Texas
2020
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($11.1)
(a)
Entergy Mississippi
Natural gas swaps
Fuel, fuel-related expenses, and gas purchased for resale
($0.8)
(a)
Entergy New Orleans
Financial transmission rights
Purchased power
$26.7
(b)
Entergy Arkansas
Financial transmission rights
Purchased power
$19.6
(b)
Entergy Louisiana
Financial transmission rights
Purchased power
$3.0
(b)
Entergy Mississippi
Financial transmission rights
Purchased power
$1.4
(b)
Entergy New Orleans
Financial transmission rights
Purchased power
$40.4
(b)
Entergy Texas
a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.
b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.
Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

quoted prices for similar assets or liabilities in active markets;
quoted prices for identical assets or liabilities in inactive markets;
inputs other than quoted prices that are observable for the asset or liability; or
inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting
market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice
President and Treasurer. The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2022 and December 31, 2021. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Mississippi

2022
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Temporary cash investments
$17.0
$—
$—
$17.0
Escrow accounts
33.5
33.5
Financial transmission rights
0.6
0.6
$50.5
$—
$0.6
$51.1
Liabilities:
Gas hedge contracts
$24.0
$—
$—
$24.0
2021
Level 1
Level 2
Level 3
Total
(In Millions)
Assets:
Temporary cash investments
$47.6
$—
$—
$47.6
Escrow accounts
48.9
48.9
Financial transmission rights
0.3
0.3
$96.5
$—
$0.3
$96.8
Liabilities:
Gas hedge contracts
$6.7
$—
$—
$6.7

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022.
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2022
$2.3
$0.6
$0.3
$0.1
$0.8
Issuances of financial transmission rights
5.4
5.3
0.8
0.8
3.9
Gains (losses) included as a regulatory liability/asset
109.1
49.9
9.9
3.6
1.7
Settlements
(106.5)
(48.5)
(10.4)
(3.7)
(6.3)
Balance as of December 31, 2022
$10.3
$7.3
$0.6
$0.8
$0.1

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021.
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(In Millions)
Balance as of January 1, 2021
$2.7
$4.2
$0.6
$0.1
$1.6
Issuances of financial transmission rights
2.8
4.1
1.7
0.4
2.7
Gains (losses) included as a regulatory liability/asset
39.4
23.9
9.3
3.9
82.4
Settlements
(42.6)
(31.6)
(11.3)
(4.3)
(85.9)
Balance as of December 31, 2021
$2.3
$0.6
$0.3
$0.1
$0.8


NOTE 16. DECOMMISSIONING TRUST FUNDS

Note 16 to the financial statements is not applicable to Entergy Mississippi.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2022
$127.5
$354.0
$1.0
$—
$18.9
$658.8
2021
$109.8
$289.9
$1.4
$—
$64.3
$545.6
2020
$105.2
$280.5
$1.2
$—
$40.4
$520.7

Intercompany Operating Expenses
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2022
$617.4
$770.2
$356.1
$341.7
$321.4
$215.0
2021
$559.7
$755.2
$299.8
$287.8
$275.0
$190.8
2020
$515.5
$661.5
$283.3
$266.0
$260.3
$177.4

Intercompany Interest and Investment Income
Entergy Arkansas
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
(In Millions)
2022
$0.1
$186.1
$0.1
$0.1
$0.3
$0.3
2021
$—
$127.6
$—
$—
$—
$—
2020
$—
$127.7
$0.1
$—
$—
$0.2


NOTE 19. SUBSEQUENT EVENT

Management has evaluated the impact of events occurring after December 31, 2022 up to April 13, 2023, the date that Entergy Mississippi’s FERC financial statements and disclosures were filed. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
166,834,143
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
197,569,752
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
6,362,389,772
6,362,389,772
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
(a)
32,202,791
32,202,791
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
469,624,376
469,624,376
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
6,864,216,939
6,864,216,939
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
220,455
220,455
11
ConstructionWorkInProgress
Construction Work in Progress
169,802,754
169,802,754
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
83,828,314
83,828,314
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
7,118,068,462
7,118,068,462
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
(b)
2,105,185,734
2,105,185,734
15
UtilityPlantNet
Net Utility Plant (13 less 14)
5,012,882,728
5,012,882,728
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
1,845,535,679
1,845,535,679
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
(c)
239,165,057
239,165,057
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
2,084,700,736
2,084,700,736
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
6,808
6,808
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
6,808
6,808
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
20,478,190
20,478,190
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
(d)
2,105,185,734
2,105,185,734


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases
Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.
(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $159,380,684.
(c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService
Includes accumulated provision for amortization of intangible assets.
(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Includes a debit balance for removal costs of $159,380,684.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
354,946,575
15,430,154
12,089
370,364,640
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
354,946,575
15,430,154
12,089
370,364,640
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
2,270,414
2,270,414
9
(311) Structures and Improvements
66,296,226
851,575
746,175
66,401,626
10
(312) Boiler Plant Equipment
312,263,587
2,973,896
1,878,354
313,359,129
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
143,789,231
3,144,823
3,291,626
143,642,428
13
(315) Accessory Electric Equipment
47,697,792
1,058,943
264,277
48,492,458
14
(316) Misc. Power Plant Equipment
11,002,554
121,617
100,450
11,023,721
15
(317) Asset Retirement Costs for Steam Production
2,008,212
2,008,212
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
585,328,016
8,150,854
6,280,882
587,197,988
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
4,253,086
4,253,086
38
(341) Structures and Improvements
330,776,657
1,718,771
109,369
332,386,059
39
(342) Fuel Holders, Products, and Accessories
8,645,077
8,645,077
40
(343) Prime Movers
349,113,026
13,876,900
11,980,263
351,009,663
41
(344) Generators
233,047,654
6,435,778
3,867,886
235,615,546
42
(345) Accessory Electric Equipment
46,506,604
1,236,998
335,657
47,407,945
43
(346) Misc. Power Plant Equipment
6,610,164
1,456,443
8,066,607
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
978,952,268
24,724,890
16,293,175
987,383,983
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
1,564,280,284
32,875,744
22,574,057
1,574,581,971
47
3. Transmission Plant
48
(350) Land and Land Rights
103,548,343
7,735,357
111,283,700
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
67,632,673
5,698,877
160,634
181,646
73,352,562
50
(353) Station Equipment
740,599,385
30,631,936
8,373,714
762,857,607
51
(354) Towers and Fixtures
56,660,103
4,449,975
428,798
60,681,280
52
(355) Poles and Fixtures
511,789,471
2,125,813
2,851,195
506,812,463
53
(356) Overhead Conductors and Devices
330,262,220
28,656,340
1,685,499
357,233,061
54
(357) Underground Conduit
1,311
1,311
55
(358) Underground Conductors and Devices
6,310
6,310
56
(359) Roads and Trails
57
(359.1) Asset Retirement Costs for Transmission Plant
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
1,810,499,816
75,046,672
13,499,840
181,646
1,872,228,294
59
4. Distribution Plant
60
(360) Land and Land Rights
21,143,751
3,274,067
24,417,818
61
(361) Structures and Improvements
23,163,614
2,005,273
135,795
25,033,092
62
(362) Station Equipment
404,455,274
28,939,100
2,042,852
431,351,522
63
(363) Energy Storage Equipment – Distribution
64
(364) Poles, Towers, and Fixtures
415,577,423
41,802,085
6,831,093
450,548,415
65
(365) Overhead Conductors and Devices
506,159,799
44,326,029
6,824,928
543,660,900
66
(366) Underground Conduit
51,739,173
3,790,383
100,555
55,429,001
67
(367) Underground Conductors and Devices
104,213,533
9,836,844
892,932
113,157,445
68
(368) Line Transformers
609,883,835
60,150,468
7,565,531
662,468,772
69
(369) Services
190,369,908
3,743,487
444,431
193,668,964
70
(370) Meters
120,479,115
26,801,858
1,183,354
146,097,619
71
(371) Installations on Customer Premises
41,521,711
5,153,101
7,462,405
39,212,407
72
(372) Leased Property on Customer Premises
73
(373) Street Lighting and Signal Systems
86,325,860
11,625,040
3,030,519
94,920,381
74
(374) Asset Retirement Costs for Distribution Plant
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
2,575,032,996
241,447,735
36,514,395
2,779,966,336
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
7,835,692
6,028
6,477
7,835,243
87
(390) Structures and Improvements
119,538,042
19,221,223
4,535,527
181,646
134,042,092
88
(391) Office Furniture and Equipment
20,081,679
1,906,403
2,537,979
19,450,103
89
(392) Transportation Equipment
261,640
261,640
90
(393) Stores Equipment
12,348
12,348
91
(394) Tools, Shop and Garage Equipment
8,328,507
541,214
30,666
8,839,055
92
(395) Laboratory Equipment
4,412,313
4,412,313
93
(396) Power Operated Equipment
64,407
64,407
94
(397) Communication Equipment
39,615,569
17,835,685
19,551
57,431,703
95
(398) Miscellaneous Equipment
1,700,317
823,686
2,524,003
96
SUBTOTAL (Enter Total of lines 86 thru 95)
201,850,514
40,334,239
7,130,200
181,646
234,872,907
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
201,850,514
40,334,239
7,130,200
181,646
234,872,907
100
TOTAL (Accounts 101 and 106)
6,506,610,185
405,134,544
79,730,581
6,832,014,148
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
6,506,610,185
(a)
405,134,544
79,730,581
6,832,014,148


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdditions
The negative project additions include reversal credits from prior year additions for unclassified project costs closed to plant in service.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Land and Land Rights Under $250,000
205,522
3
21 Other Property:
22
Other Property Under $250,000
14,933
47 TOTAL
220,455


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
2020 - Focus - FC20M048 - Madison -
262,196
2
2020 - RANKIN - AIRPORT - 6A04 - 55
334,865
3
2020 - SOUTHAVEN - PLUM POINT - CHU
356,046
4
2020 Planning CL20-005V New Build N
240,021
5
2020 Planning CL20-005V Rep A1, RRE
406,457
6
2021 - SENATOBIA - LULA - 1K01 - Q1
109,288
7
2021 Planning MD21-002A Rebuild R1
495,373
8
2021-GRENADA-ENID 2B01-MDOT BRIDGE
252,582
9
2021-SA20M014-Senatobia-1H05
254,436
10
2022 Woodrow Wilson Relocation
155,027
11
2022-CLINTON-TERRY SUB-7B04-JF073-H
358,057
12
2022-Grenada-Grenada-2L02-Milwaukee
1,207,725
13
2022-GRENADA-MILWAUKEE TOOL PART 3
1,227,724
14
2022-MADISON-CHARITY CHURCH-RELOCAT
876,526
15
2022-Southern Sky-Install Permanent
154,476
16
2023-Madison-Canton-Fac Relocation
108,855
17
9C01- State Line Exploration- 3-pha
260,315
18
AD21M004 - FOCUS - 1D02 - K1511
133,438
19
Add Ckt. 9A06  to Poleline for Seco
133,780
20
Baird, Baird Rd, Mathew Miller Irri
153,880
21
BROOKHAVEN-905 INDUSTRIAL PARK RD N
350,003
22
Build Ckt. 8M10 for Dedicated Feed
290,669
23
Build Ckt. 8M10 to Feed Rex Lumber
315,862
24
Case #10457 - Southaven - Holly Rid
105,657
25
Downtown Jackson - Replace 1500 KVA
155,208
26
EDWARDS-JACKSON STREET-RELOCATE REG
119,542
27
EMI 2022 Dec Storm Dist Ops - MS
1,321,524
28
EMI 2022 Nov Storm Dist Ops - MS
2,127,680
29
EMI 2022 Oct Storm Dist Ops - MS
446,361
30
FLIP North Coldwater 1L04 SCOPING
803,273
31
GM - Guild 33 - FA06 - Rebuild - Cl
494,581
32
GM - Guild 33 - FJ05 - Rebuild - Hi
130,645
33
GM-Guild 33-FA06-Rebuild-Cleary Rd
290,955
34
GM-Guild 33-FJ05-Rebuild-Hickory Ri
243,917
35
GM-Guild 33-GK01-Rebuild-Brookwood
129,868
36
GM-Vicksburg SE Guild 5F02-IA1; 5F0
165,827
37
GM-Vicksburg SE Guild 5F02-IREG1, I
286,217
38
GM-Vicksburg SE Guild 5F02-R1, R2,
157,589
39
GM-Vicksburg SE Guild 5F03-N6, FSW1
2,806,995
40
GM-Vicksburg SE Guild 5F03-N7, N8,
200,924
41
GM-Vicksburg SE Guild 5F03-R8 part
173,013
42
Hernando-Getwell Rd.-Short Fork Dev
114,511
43
Hernando-Wooten Dr.-Winningham Esta
116,491
44
HIGHWAY - GRANTS FERRY PARKWAY RELO
158,136
45
HWY-2020-GM01-DF400-BOZEMAN RD UG 2
370,780
46
JACKSON - E. CAPITOL ST. - CITY OF
169,518
47
JACKSON-VALLEY PARK II-PROVIAS CONS
191,897
48
Madison 115kV Second Xfmr T&D
110,126
49
Madison-Lake Village Drive-Reunion
152,052
50
Mannsdale T&D D-Scoping
198,008
51
Pine Tree Substation T&D D-Scoping
422,479
52
PSK405-1Y06-MALONE-MAJOR EQUIPMENT
154,088
53
Rankin Industrial - OH to UG Highwa
1,197,344
54
Relocate Facilities W Capitol St
487,292
55
REVENUE - WEST POINT SUBDIVISION PH
286,558
56
SE21-004V EMI Sycamore Wakefield RO
306,095
57
SH21-011V NRT - Multiphase Addition
111,769
58
SH21-012V Lewisburg School Project
298,279
59
SH21-013A Lewisburg School Scoping
382,118
60
SNOWDEN PARK DIST. ROW
721,613
61
SOUTHAVEN - CITY WIDE LED CONVERSIO
362,485
62
Southaven-Getwell Road-M&R Builders
146,857
63
T&D - Snowden Park - FDR1,2 - Rebui
261,076
64
T&D - Snowden Park - FDR1,3 - Rebui
103,881
65
T&D - Snowden Park - FDR1,3 - UG Ne
261,347
66
T&D - Snowden Park - FDR2 - New Bui
799,831
67
T&D - Snowden Park - FDR2 Major Equ
108,651
68
T&D - Snowden Park - FDR3 -  New Bu
429,729
69
T&D - Snowden Park - FDR3 - Rebuild
248,923
70
T&D - Snowden Park - FDR3,4,5 - New
116,824
71
T&D - Snowden Park - FDR4 - New Bui
525,955
72
T&D - Snowden Park - FDR4 - Rebuild
198,503
73
T&D - Snowden Park - FDR5 - New Bui
192,138
74
T&D - Snowden Park - FDR5 - Rebuild
618,149
75
T&D - Snowden Park - New Build - UG
457,568
76
UPIC - Hernando-Robertson Gin Rd.-M
178,947
77
UPIC-Canton-Oakfield Blvd- Stillhou
138,938
78
UPIC-DESOTO COUNTY-GETWELL RD-SHORT
106,473
79
UPIC-Hernando-Laughter Road S-Mille
110,983
80
UPIC-HORN LAKE-WILLOW OAK DR-WILLOW
105,935
81
UPIC-Madison Co -Baleigh Dr.-Glenda
109,064
82
UPIC-Madison-Deweese Rd.-Westlake M
108,754
83
UPIC-Southaven-Rasco Rd-Johnny Cole
134,824
84
OTHER DISTRIBUTION LINES PLANT
7,258,690
85
2022 Customer NPS
163,110
86
2022 Data Analytics Platform - AWS
241,804
87
2022 Dist Capital Tools EML
1,244,175
88
2022 MISO Predictive Analytics
155,955
89
3.12 Upgrade/Fault Location
3,217,829
90
Accrual Capital Proxy Code
248,130
91
AMI - DMS/OMS - Software - Rel 4-5
2,781,226
92
Asset Suite/AIMM Repl - Supply Chai
10,081,943
93
Attachments Data System (ADS)
258,011
94
CSD Workforce Management System
689,857
95
DA Settings Management
166,390
96
Digital LIHEAP
514,699
97
Dist.Transformers Outage Prediction
170,045
98
Distribution Resiliency Plan
251,581
99
EMI: Camlin Pilot Franklin EHV
344,814
100
EML Public EV Charging Pilot
141,096
101
EML: Camlin Pilot - Baxter Wilson
258,611
102
EPG GridUnity
244,009
103
FLY - Flora Transmission Laydown YD
3,509,440
104
FTO - Flora Transmission Office
10,948,923
105
IBM MRO IO Entergy Interface
115,978
106
Miss. Signage Rebranding Costs
1,055,179
107
P2R Upgrade 2022-23
139,295
108
PGen Smart Procedures
343,744
109
PI Vision
121,508
110
PowerPlan Upgrade 2022
112,633
111
Pwr Gen Remote Ops Project
297,965
112
PWTHR IT Systems
117,802
113
Rotating Load Shed Software Imp
137,124
114
SIEM Optimization
192,145
115
SW2 - EDE-Bill Syst Contr Repo Inte
646,602
116
SW-Facilities Ratings WS-NERC Rep
274,405
117
SW-Network Access Control Authentic
191,305
118
Video Management Solution Project
119,953
119
OTHER GENERAL & INTANGIBLE PLANT
986,805
120
A1A - GE LTSA Budget Cap 2020-2024
13,794,238
121
CO1 - Choctaw Emergency Generator
799,337
122
CO1 Additional Warehouse With Cont
942,335
123
CO1 LTSA Capitalization
2,491,641
124
EMI Sunflower County SolarOversight
3,676,189
125
HN1 - Hinds LTSA Capital
10,578,192
126
RXC Lake Hico Closure Plan
154,980
127
SPO EMISunflowerCoSolarBOTTransactn
2,872,121
128
SPO EML SunflowerTaxEquityPartneshp
3,146,274
129
Sunflower Betterment Spend Approach
1,030,038
130
OTHER PRODUCTION PLANT
11,786
131
Brookhaven Upgrade Transformer
883,967
132
Build New Grenada Industrial 115kV
137,982
133
Build Pine Tree 230/12.47kV Sub
1,372,707
134
Canton Rd:  Install Circuit Swi, Re
234,729
135
CE Whitfield 115kV Add Breakers
799,873
136
Clarksdale replace transformer J292
293,716
137
Clinton 115 kV Sub - Install T-Brkr
741,985
138
Crenshaw: Add Circuit Switcher
246,785
139
EMI: Camlin Pilot (Freeport)
277,786
140
EMI: Camlin Pilot (Lakeover)
555,572
141
EMI: Camlin Pilot (Ray Braswell)
185,191
142
EML C Spire - Northern Route
1,625,549
143
EML C Spire - Southern Route
401,950
144
EML: 115-13.8 | 20MVA (Marvell)
934,072
145
EML: 115-13.8kV | 20MVA LTC
1,022,266
146
EML: 115kV|40kA|3000A Blue Breaker
156,712
147
EML: AC Reactor for Ray Braswell
111,232
148
Franklin 115kV SPOF
120,177
149
Hollandale: E&D 3J22 & 3J02.
372,738
150
Indianola RE-McAdms Rly Imprv.SPOF
124,406
151
Inverness replace transformer J0135
287,563
152
Lakeover: Replace J9234 Breaker
172,489
153
Lexington 115kv RplcXfmr-Scoping
714,562
154
Madison 115kV - Add 2nd Transformer
703,384
155
Mannsdale 230kV Substation
732,546
156
Marks Add Circuit switchers & repla
233,133
157
McAdams Relay Imprv. SPOF
624,925
158
Midnight: rpl ABS J0348 & Steel Bus
167,800
159
Midnight: rpl Oil Pump on J0346
114,945
160
Northpark: Add 230/115kV-400MVA Aut
9,312,544
161
Rankin 115kV Sub - Add Line Bay
1,805,490
162
Sardis: E&D 1A22 & 24 Bkr Rpl
247,246
163
Snowden Park-Bld 115kV Sub-Scoping
7,329,625
164
Terry:  E&D 7B24 & 7B03 Bkr Rpl
172,690
165
Vicksburg N: Rpl 115KV Bus Diff Pan
136,500
166
Vicksburg Openwd 115kVSub-AddTransf
913,982
167
Whitfield: add Ckt Sw, rpl T1 Diff
144,506
168
OTHER TRANSMISSION & DISTRIBUTION SUBS
1,833,295
169
Bowling Green - Durant 115kV CAP
145,372
170
C6ML300002: Horn Lake - DeSoto 115k
317,416
171
C6ML300036:  Nitta Yuma - Rolling F
445,170
172
C6ML300039: Desoto - Walls 115kV CA
736,941
173
C6ML300040: S. Natchez - Natchez In
838,720
174
C6ML300042: Ray Braswell - Clinton
447,218
175
C6ML300043: Horn Lake - Greenbrook
221,690
176
C6ML300045: Canton - S. Canton 230k
619,890
177
C6ML300051: Flowers - Openwood 115k
127,427
178
C6ML300057: East Jackson - Fannin R
151,432
179
C6ML300058: E. Jackson - S. Jackson
206,626
180
C6ML300059: Liberty - Gillsburg 115
491,071
181
C6ML300060 Liberty - Gloster 115kV
301,458
182
C6ML300068: Natchez to Washington S
190,167
183
C6ML300069: Washington to Cranfield
167,201
184
C6ML300080:  Flora - Little Yazoo (
348,307
185
E. Vicksburg-E. Vicksburg 115kV CAP
125,595
186
Franklin-GGNS 500Kv Phase Swa
1,078,583
187
Gerald Andrus - Tinnin Rd 230kV CAP
230,793
188
Getwell-Twinkletown 230kV Cut-In
1,127,337
189
Greenbrook to Snowden Park 115kv Ln
751,666
190
Greenville TCEPA - Arcola 115kV CAP
243,883
191
Greenwood-Itta Bena 115Kv Cut-In
371,097
192
Indianola - Tillatoba 230kV CAP
165,578
193
Lakeover-Hinds 230kV CAP
301,669
194
MDOT-DeSotoCnty-ReloStr(HrnLk-Grnb)
335,703
195
MDOT-DeSotoCtyTLnReloc(HrnLk-Getwl)
116,747
196
Pelahatchie - Rankin 115kV CAP
176,991
197
Plum Point to Snowden Prk -115kv Ln
429,050
198
OTHER TRANSMISSION LINES PLANT
679,846
199
UNDISTRIBUTED OVERHEADS:
4,053,212
43 Total
169,802,754


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
1,757,313,768
1,757,306,960
6,808
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
215,323,254
(a)
215,323,254
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
11,486
11,486
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
17,747
(b)
17,747
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
215,352,487
215,352,487
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
79,718,491
(c)
79,718,491
13
CostOfRemovalOfPlant
Cost of Removal
49,992,707
49,992,707
14
SalvageValueOfRetiredPlant
Salvage (Credit)
2,332,367
2,332,367
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
127,378,831
127,378,831
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
255,063
(d)
255,063
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
1,845,542,487
1,845,535,679
6,808
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
407,604,718
407,602,333
2,385
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
376,249,202
376,249,202
25
AccumulatedDepreciationTransmission
Transmission
463,216,254
463,211,831
4,423
26
AccumulatedDepreciationDistribution
Distribution
562,096,891
562,096,891
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
36,375,422
36,375,422
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
1,845,542,487
1,845,535,679
6,808


FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments
Excludes service company depreciation allocations of $3,775,889 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated reserves.
(b) Concept: OtherAccounts
Includes depreciation on Gerald Andrus pipelines and Independence, which is accounted for as fuel expense.
(c) Concept: BookCostOfRetiredPlant
Excludes retirements of $12,090 (included in Amortization of Other Utility Plant shown on pages 204 - 207), since these retirements do not offset to accumulated depreciation reserves.
(d) Concept: OtherAdjustmentsToAccumulatedDepreciation
Southhaven: Sale of Land ($141,009)
Rex Brown settlement of ARO 396,072 
Total $255,063 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
EMI New Nuclear, LLC - Subsidiary Company Subheading
09/18/2008
2
EMI New Nuclear, LLC - Capital Contribution
5,695
95,606,559
95,612,254
3
EMI New Nuclear, LLC - Unappropriated Undistributed Subsidiary Earnings
3,695
213,506
209,811
4
EMI New Nuclear, LLC - Subtotal
2,000
213,506
95,606,559
95,822,065
5
Mississippi Power & Light Co. - Subsidiary Company Subheading
6
Mississippi Power & Light Co. - Capital Contribution
517
517
7
Mississippi Power & Light Co. - Unappropriated Undistributed Subsidiary Earnings
275
275
8
Mississippi Power & Light Co. - Subtotal
242
242
42
Total Cost of Account 123.1 $
Total
2,242
213,506
95,606,559
95,822,307


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
10,290,914
15,537,354
2
Fuel Stock Expenses Undistributed (Account 152)
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
(a)
56,438,756
(b)
63,854,011
Electric
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
8,799,360
12,888,585
Electric
8
Transmission Plant (Estimated)
112,746
55,766
Electric
9
Distribution Plant (Estimated)
777,069
3,375,013
Electric
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
66,127,931
80,173,375
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
3,510,746
4,172,529
17
18
19
20
TOTAL Materials and Supplies
79,929,591
99,883,258


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
BEG OF YEAR
Production (estimated) $29,883,419 
Transmission (estimated) 6,207,344 
Distribution (estimated) 20,347,993 
Total Assigned to Construction (estimated) $56,438,756 
(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction
BALANCE AT
 END OF YEAR
Production (estimated) $28,303,614 
Transmission (estimated) 11,659,903 
Distribution (estimated) 23,890,494 
Total Assigned to Construction (estimated) $63,854,011 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
163,929
163,929
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
15,931
15,930
15,930
15,930
(a)
430,117
493,838
0
5
Returned by EPA
6
7
8
Purchases/Transfers:
75
75
9
10
11
12
13
14
15
Total
75
75
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
Compliance Deduction
3,123
3,123
23
24
25
26
27
28
Total
3,123
3,123
29
Balance-End of Year
176,812
15,930
15,930
15,930
430,117
654,719
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2026 through 2052.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
1,125
20,170
1,125
20,170
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
2,363
2,313
2,313
2,313
(a)
4,626
13,928
5
Returned by EPA
6
7
8
Purchases/Transfers:
9
Current Period Adjustment
244
244
10
11
12
13
14
15
Total
244
244
16
17
Relinquished During Year:
18
Charges to Account 509
1,506
9,363
1,506
9,363
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
1,738
10,807
2,313
2,313
2,313
4,626
13,303
10,807
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber
Future years include allowances issued from 2026 through 2027.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20 TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Total
21
Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
Total
40 Grand Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022
4,068,765
57,396
4,011,369
2
MISO Financial Transmission Rights Mark-to-Market
402,585
402,585
3
Asset Retirement Obligation - Fossil
7,882,513
863,557
3,087,180
5,658,890
4
Asset Retirement Obligation - Coal
536,034
113,343
649,377
5
Defined Benefit Pension & Other Post Retirement Plans
172,184,550
26,690,296
145,494,254
6
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020
1,838,085
191,799
1,646,286
7
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021
11,996,710
1,262,811
10,733,899
8
Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020
20,510,698
4,826,046
15,684,652
9
Deferred Electric Storm Restoration Costs
5,760,571
5,760,571
10
Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021
7,417,722
7,417,722
11
Electric Deferred Fuel Under-Recovery
121,878,218
219,664,992
198,332,480
143,210,730
12
Energy Efficiency Rider Under-Recovery
12,115,963
11,097,636
23,213,599
13
Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39
430,216
379,408
809,624
14
Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205 - Amort pd Aug 2022 thru June 2023
19,000,000
13,652,402
15,677,126
16,975,276
15
Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132
27,363,115
4,000,250
31,363,365
16
Grand Gulf Under-Recovery MPSC Docket No. 1984-UN-4620
20,164,570
20,164,570
17
Unit Power Cost Recovery Rider Under-Recovery MPSC Docket No. 2014-UN-132
6,420,161
6,420,161
18
COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205 - Amort 36 months beg April 2022
13,132,315
3,283,079
9,849,236
19
Income Taxes
25,118,080
450,167
25,568,247
20
Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205
18,200,000
18,200,000
21
Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022
8,007,391
140,307
7,867,084
22
Derivative Instruments and Hedging Activities
6,709,364
17,293,684
24,003,048
23
Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 Amort July 2021-June 2022
1,839,231
1,839,231
24
Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 Amort April 2021-Mar 2022
430,335
430,335
25
Vegetation Management Rider MPSC Docket No. 2018-UN-205
728,394
728,394
26
Formula Rate Plan 2022 Settlement MPSC Docket No. 2018-UN-205 Amort 8 months beg Aug 2022
8,899,790
5,743,649
3,156,141
44
TOTAL
457,274,699
333,276,116
275,871,007
514,679,808


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
ISES Acquisition Adjustment
178,200
178,200
2
Non-Expense Accrued Labor
2,013,746
432,151
2,445,897
3
Section 263A
109,910
15,701
94,209
4
Mark-to-Market
13,244
1,325
11,919
5
Other
119,910
119,910
47
Miscellaneous Work in Progress
48
Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49
TOTAL
2,315,100
2,671,935


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
(a)
See Footnote
602,399,094
570,309,487
7
Other
8
TOTAL Electric (Enter Total of lines 2 thru 7)
602,399,094
570,309,487
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
602,399,094
570,309,487
Notes


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax
BALANCE AT BEG OF YEAR BALANCE AT END OF YEAR
Abandonment Loss $1,425,680  $1,425,679 
Intrst/Tax Tax Deficiencies 324,350  324,350 
Taxable Unbilled Revenue 2,306,012  5,825,593 
Property Insurance Reserve 6,842,571  8,394,339 
Capitalized Repairs 343,363  233,263 
Injuries & Damages Reserve 1,104,343  948,269 
Contribution in Aid of Construction 8,597,766  10,957,425 
Pension Plan (22,836,428) (22,889,667)
Defined Benefit Pension 41,545,899  34,978,624 
Supplemental Pension Plan 583,765  633,459 
Other Post Employment Benefits (8,530,942) (9,831,174)
Deferred Fuel (1,601,816)
Removal Cost (23,678,581) (27,702,686)
Accrual of Reserves 15,974  19,222 
Asset Retirement Obligation 1,006  1,006 
Litigation Settlement 62,375  — 
Accrued Medical Claims 738,291  635,336 
Uncollectible Accounts 1,798,671  616,643 
Def Gain/Basis Step-Up 215,142  193,621 
Basis Step-Up 3,209,109  2,916,744 
Regulatory Liability (3,461,813) (2,339,063)
Partnership Income/Loss 2,052  2,835 
Contract Deferred Revenue 55,866  35,506 
Lease - Rental Expense 93,946  127,684 
Environmental Reserve 103,792  15,968 
Incentive Compensation 1,880,868  2,040,822 
Long-Term Incentive Compensation 76,358  92,750 
Stock Options 23,748  37,157 
Restricted Stock Awards 200,207  145,767 
Transition Costs 300,735  — 
Income Tax Adjustment 61,994,672  60,433,369 
Tax Attribute - NOL/CR Carryforward 2,509,371  2,509,371 
ADIT-NOL-SRLY Fed NonCur 280,290,570  400,724,730 
ADIT-Tax CR Carryforward 3,322,111  10,100,568 
Fed Offset-St Carryover (24,194,989) (22,814,841)
ADIT NOL Carryforward 263,106,165  106,991,580 
ADIT-Ben-Potnt Disall UTPs Res 2,027,068  6,127,054 
TOTAL $602,399,094  $570,309,487 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
3
4
5
Total
6
Preferred Stock (Account 204)
7
8
9
10
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5
Total


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-04-13
Year/Period of Report

End of:
2022
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
329,266,361
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
16
MiscellaneousPaidInCapital
Ending Balance Amount
329,266,361
17
OtherPaidInCapitalAbstract
Historical Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
329,266,361


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
3.1% Series
250,000,000
1,992,167
985,000
12/11/2012
07/01/2023
12/11/2012
07/01/2023
250,000,000
7,750,000
3
3.75% Series
100,000,000
954,738
30,000
03/21/2014
07/01/2024
03/21/2014
07/01/2024
100,000,000
3,750,000
4
2.85% Series
375,000,000
2,878,733
120,000
05/13/2016
06/01/2028
05/13/2016
06/01/2028
375,000,000
10,687,500
5
4.9% Series
260,000,000
8,107,303
09/15/2016
10/01/2066
09/15/2016
10/01/2066
260,000,000
12,740,000
6
3.25% Series
150,000,000
1,362,173
511,500
11/14/2017
12/01/2027
11/14/2017
12/01/2027
150,000,000
4,875,000
7
4.52% Series
55,000,000
511,787
12/12/2018
12/01/2038
12/12/2018
12/01/2038
55,000,000
2,486,000
8
3.85% Series 1
300,000,000
3,171,620
3,891,000
06/05/2019
06/01/2049
06/05/2019
06/01/2049
300,000,000
11,550,000
9
3.85% Series 2
135,000,000
1,395,028
10,813,500
11/19/2019
06/01/2049
11/19/2019
06/01/2049
135,000,000
5,197,500
10
3.5% Series 1
170,000,000
2,166,734
2,410,600
05/22/2020
06/01/2051
05/22/2020
06/01/2051
170,000,000
5,950,000
11
3.5% Series 2
200,000,000
2,150,279
2,754,000
03/12/2021
06/01/2051
03/12/2021
06/01/2051
200,000,000
7,000,000
12
2.55% Series
200,000,000
1,783,526
516,000
11/16/2021
12/01/2033
11/16/2021
12/01/2033
200,000,000
5,100,000
13
Subtotal
2,195,000,000
26,474,088
13,567,500
8,464,100
2,195,000,000
77,086,000
14
Reacquired Bonds (Account 222)
15
16
17
18
Subtotal
19
Advances from Associated Companies (Account 223)
20
21
22
23
Subtotal
24
Other Long Term Debt (Account 224)
25
Term Loan
150,000,000
121,554
06/29/2022
12/29/2023
06/29/2022
12/29/2023
150,000,000
2,958,224
26
Revolving Credit Facility
1,702,715
27
Subtotal
150,000,000
121,554
150,000,000
4,660,939
33 TOTAL
2,345,000,000
2,345,000,000
(a)
81,746,939


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: InterestExpenseOnLongTermDebtIssued
Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
197,569,752
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
(a)
See Footnote Detail
36,454,192
9
Deductions Recorded on Books Not Deducted for Return
10
(b)
See Footnote Detail
2,727,977
14
Income Recorded on Books Not Included in Return
15
(c)
See Footnote Detail
5,475,185
19
Deductions on Return Not Charged Against Book Income
20
(d)
See Footnote Detail
104,170,211
21
(e)
Other Reconciling Items - See footnote detail
127,202,440
27
Federal Tax Net Income
95,915
28
Show Computation of Tax:
29
Normal and Surtax @ 21%
20,142
30
(f)
Estimated Consolidated Income Tax Allocated - See Footnote Detail


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription
Taxable Income Not Recorded on Books:
Avoided Cost - Tax Interest $5,563,218 
Contributions in Aid of Construction 12,235,509 
Deferred Contract Revenue 48,930 
Obligation for Customer Credits 4,500,000 
Unbilled Revenue 14,106,535 
Total $36,454,192 
(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription
Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves $4,496,839 
Deferred Compensation and Benefits 1,673,565 
Meals and Entertainment 35,509 
Penalties 11,262 
Political Expenses 740,250 
Reserve for Uncollectible Accounts (4,229,448)
Total $2,727,977 
(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription
Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction $5,264,819 
Equity Earnings in Subs 213,506 
Tax Equity Partnership (3,140)
Total $5,475,185 
(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets $24,866,334 
Amortization of Regulatory Assets (5,122,310)
Bond Reacquisition Loss (1,293,069)
Deferred Compensation & Benefits 127,568 
Deferred Fuel 27,752,673 
Depletion 292 
Depreciation of Plant Assets 17,254,946 
Service Company Billings 1,772,456 
Grand Gulf 1 Costs 20,164,570 
Pension and OPEB 5,549,164 
Prepaid Expenses (1,181,816)
Research and Development Costs (6,497,070)
Software Costs 1,098,759 
UOP Repairs 19,677,714 
Total $104,170,211 
(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription
Reconciling Items for the Year:
Net Operating Loss ($182,071,355)
Federal Income Tax Accrual - Current year (20,142)
Federal Income Tax Accrual - Prior year 9,262,699 
Investment Tax Credit 3,664,589 
FIN 48 taxes 100,757,352 
Provision for Deferred Income Tax (52,314,136)
State Income Tax - Current Year 5,048 
State Income Tax Accrual - Prior Year (6,486,496)
Total ($127,202,441)
(f) Concept: ComputationOfTaxDescription
The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2022. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:
FOOTNOTE DATA
Entergy Utility Property, Inc. ($14,000)
Entergy Utility Affiliates, LLC (10,000)
Entergy Utility Assets Holdings, Inc. 1,437,000 
Entergy Utility Group, Inc. (15,000)
System Energy Resources, Inc. (1,217,000)
Entergy Operations, Inc. (36,000)
Entergy Corporation (33,786,000)
Entergy Nuclear New York Investment Company, LLC 566,000 
Entergy Nuclear Holding Company #3, LLC (2,379,000)
Entergy Assets Management Company, LLC (2,697,000)
Entergy Northeast Holdings, LLC (13,801,000)
Entergy Power Marketing Holding II, Inc. (75,000)
Entergy Nuclear Power Marketing, LLC 1,594,000 
Entergy Nuclear, Inc. (209,000)
Entergy Nuclear Holding Company #1 (3,394,000)
Entergy Nuclear Operations, Inc. (11,005,000)
Entergy Power Holdings, Inc. 4,821,000 
Entergy TransCo HoldCo, LLC (5,000)
EAM Nelson Holding, LLC 70,000 
Entergy Power Investment Holding, Inc. 5,082,000 
Entergy Mississippi Turbine Company (70,000)
Entergy Power, LLC (110,000)
Entergy Enterprises, Inc. (24,000)
Entergy Power Gas Operations, LLC 15,183,000 
Entergy Power Marketing Holding I, Inc. (3,457,000)
Entergy Power Operations U.S., Inc. 328,000 
Entergy Nuclear Palisades, LLC (6,770,000)
EWO Marketing, LLC (844,000)
Entergy Global, LLC (58,000)
Entergy Utility Assets, LLC 3,000 
Entergy Ventures, Inc. (52,000)
EUP Holdings, LLC 226,000 
Entergy Assets Management Holding, Inc. (26,000)
Entergy Technology Company (3,000)
Entergy TransCo Texas, LLC (8,000)
Entergy Services Holding, Inc. (3,804,000)
Entergy Asset Management, Inc. 6,713,000 
EWO Wind II, LLC (13,000)
Entergy Nuclear Indian Point 2, LLC (7,654,000)
Entergy Nuclear Indian Point 3, LLC (8,737,000)
Entergy Finance Company, LLC 96,998,000 
Entergy New Orleans, LLC (532,000)
Entergy Utility Holding Company, LLC (32,156,000)
Morpheus One Holdings, LLC (60,000)
Total $— 
FOOTNOTE DATA

Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC ($65,590,000)
Entergy Arkansas, LLC (10,716,000.00)
Entergy Mississippi, LLC (556,000.00)
Entergy Utility Holding Company, LLC 44,706,000.00 
Total ($32,156,000)
Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc. ($2,705,000)
Entergy Services, LLC (65,000.00)
Entergy Account Services, LLC (1,034,000.00)
Total ($3,804,000)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Federal Income Tax
Federal Tax
48,670,259
0
108,270,407
3,719,000
160,659,666
108,790,456
520,049
2
FICA
Federal Tax
2,640,538
0
6,661,466
8,444,526
857,478
3,277,227
3,384,239
3
Federal Uemployment Tax
Federal Tax
8,234
0
37,494
36,847
7,587
18,419
19,075
4
Federal Excise Tax
Federal Tax
0
0
10,238
10,238
0
10,238
0
5
Subtotal Federal Tax
51,302,563
0
114,979,605
4,772,611
0
161,509,557
0
112,096,340
0
0
2,883,265
6
State Income Tax
State Tax
1,108,646
0
6,583,377
1,676,932
3,797,799
6,453,039
130,338
7
0
0
0
0
8
Subtotal State Tax
1,108,646
0
6,583,377
1,676,932
0
3,797,799
0
6,453,039
0
0
130,338
9
Franchise - City
Local Tax
4,194,772
0
16,847,475
16,305,108
4,737,139
16,847,475
0
10
Subtotal Local Tax
4,194,772
0
16,847,475
16,305,108
0
4,737,139
0
16,847,475
0
0
0
11
Privilege License
Other Taxes
0
63,055
79,559
79,634
0
63,130
79,559
0
12
Regulatory Commission
Other Taxes
0
0
1,144,715
1,144,715
0
2,289,430
1,144,715
13
Subtotal Other Tax
0
63,055
1,224,274
1,224,349
0
0
63,130
2,368,989
0
0
1,144,715
14
Subtotal Property Tax
0
0
0
0
0
0
0
0
0
0
0
15
Subtotal Real Estate Tax
0
0
0
0
0
0
0
0
0
0
0
16
State Unemployment Tax
Unemployment Tax
90,793
0
36,726
35,099
92,420
18,410
18,316
17
Subtotal Unemployment Tax
90,793
0
36,726
35,099
0
92,420
0
18,410
0
0
18,316
18
State Use Tax
Sales And Use Tax
1,056,833
0
7,974,007
7,992,525
1,038,315
7,974,007
19
Subtotal Sales And Use Tax
1,056,833
0
7,974,007
7,992,525
0
1,038,315
0
0
0
0
7,974,007
20
Entergy Services, LLC
Income Tax
0
0
0
1,126,384
1,126,384
21
Subtotal Income Tax
0
0
0
0
0
0
0
1,126,384
0
0
1,126,384
22
State Excise Tax
Excise Tax
0
0
12,963
12,963
0
12,963
0
23
Subtotal Excise Tax
0
0
12,963
12,963
0
0
0
12,963
0
0
0
24
Subtotal Fuel Tax
0
0
0
0
0
0
0
0
0
0
0
25
Subtotal Federal Insurance Tax
0
0
0
0
0
0
0
0
0
0
0
26
Corporate Franchise Tax-MS
Franchise Tax
0
684,712
4,538,949
3,810,000
44,237
4,205,451
333,498
27
Corporate Franchise Tax-AR
Franchise Tax
0
17
2
19
150
150
28
Subtotal Franchise Tax
0
684,729
4,538,949
3,810,000
0
44,239
19
4,205,601
0
0
333,348
29
Non Income Tax
Miscellaneous Other Tax
1,300,000
0
1,300,000
0
30
Subtotal Miscellaneous Other Tax
1,300,000
0
0
0
0
1,300,000
0
0
0
0
0
31
Subtotal Other Federal Tax
0
0
0
0
0
0
0
0
0
0
0
32
Receipts & Sales
Other State Tax
2,092
0
24,945
24,937
2,100
24,945
0
33
Subtotal Other State Tax
2,092
0
24,945
24,937
0
2,100
0
24,945
0
0
0
34
Subtotal Other Property Tax
0
0
0
0
0
0
0
0
0
0
0
35
Subtotal Other Use Tax
0
0
0
0
0
0
0
0
0
0
0
36
Ad Valorem Tax - MS
Other Ad Valorem Tax
98,568,000
0
113,823,067
98,885,903
113,505,164
106,239,779
7,583,288
37
Ad Valorem Tax - AR
Other Ad Valorem Tax
1,228,000
0
1,249,723
1,235,772
1,241,951
1,259,637
9,914
38
Subtotal Other Advalorem Tax
99,796,000
0
115,072,790
100,121,675
0
114,747,115
0
107,499,416
0
0
7,573,374
39
Subtotal Other License And Fees Tax
0
0
0
0
0
0
0
0
0
0
0
40
Subtotal Payroll Tax
0
0
0
0
0
0
0
0
0
0
0
41
Subtotal Advalorem Tax
0
0
0
0
0
0
0
0
0
0
0
42
Entergy Services, LLC
Other Allocated Tax
0
0
0
3,256,095
3,256,095
43
Subtotal Other Allocated Tax
0
0
0
0
0
0
0
3,256,095
0
0
3,256,095
44
Subtotal Severance Tax
0
0
0
0
0
0
0
0
0
0
0
45
Subtotal Penalty Tax
0
0
0
0
0
0
0
0
0
0
0
46
Subtotal Other Taxes And Fees
0
0
0
0
0
0
0
0
0
0
0
40
TOTAL
158,851,699
747,784
254,128,357
132,622,335
0
279,673,086
63,149
241,003,579
0
0
13,124,778


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
4
7%
5
10%
4,602,796
410,193
223,477
4,789,512
(a)
20.5 years
8
TOTAL Electric (Enter Total of lines 2 thru 7)
4,602,796
410,193
223,477
4,789,512
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
`
11
Mississippi ITC
6,309,984
5,049,700
173,511
(b)
1,384,219
9,801,954
47 OTHER TOTAL
6,309,984
5,049,700
173,511
1,384,219
9,801,954
48 GRAND TOTAL
10,912,780
5,459,893
396,988
1,384,219
14,591,466


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome
Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.
(b) Concept: AccumulatedDeferredInvestmentTaxCreditsAdjustments
Pre-utilization period amortization.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
Long-Term Incentive Plan
306,044
144,264
209,964
371,744
2
Non-Qualified Pension funded status
3,518,273
160,542
257,765
3,615,496
3
Qualified Pension funded status
92,434,187
38,029,897
853,516
55,257,806
4
Liberty Development
285,000
285,000
5
Electric Line Justificantion Extension
233,900
233,900
6
Employment Litigation
250,000
250,000
7
Deferred rebate
931
931
8
Other
9,430
12,630
3,200
47
TOTAL
96,517,003
38,597,333
1,844,276
59,763,946


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report


End of:
2022
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
704,675,180
61,427,715
57,886,080
182.3/254
30,102
182.3/254
8,743,066
716,929,779
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
704,675,180
61,427,715
57,886,080
30,102
8,743,066
716,929,779
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
704,675,180
61,427,715
57,886,080
30,102
8,743,066
716,929,779
10
Classification of TOTAL
11
Federal Income Tax
579,342,615
47,243,212
48,339,552
8,743,066
586,989,341
12
State Income Tax
125,332,565
14,184,503
9,546,528
30,102
129,940,438
13
Local Income Tax


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
(a)
See Footnote Detail
562,842,228
88,357,416
169,202,929
6,567,283
112,317
475,541,749
9 TOTAL Electric (Total of lines 3 thru 8)
562,842,228
88,357,416
169,202,929
6,567,283
112,317
475,541,749
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
562,842,228
88,357,416
169,202,929
6,567,283
112,317
475,541,749
20
Classification of TOTAL
21
Federal Income Tax
450,248,561
72,654,071
137,298,078
190
5,251,196
182.3/254
89,808
380,443,166
22
State Income Tax
112,593,667
15,703,345
31,904,851
190
1,316,087
182.3/254
22,509
95,098,583
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther
CHANGES DURING YEAR
BALANCE AT
BEGINNING
OF YEAR
AMOUNTS
DEBITED
TO ACCT.
410.1
AMOUNTS
CREDITED
TO ACCT.
411.1
AMOUNTS
DEBITED
TO ACCT.
410.2
AMOUNTS
CREDITED
TO ACCT.
411.2
Deferred Fuel $30,408,615  $58,207,392  $52,884,919  $—  $— 
Reg Asset Covid 19 3,735,401  53,784  1,331,801  —  — 
Reg Asset-Securitization 22,829,704  20,030,008  13,781,397  —  — 
Prepaid Expenses —  5,242,788  211,728  —  — 
Minimum Pension Liability 41,545,882  —  —  —  — 
Bond Reacquisition Loss 3,033,863  13,577  336,198  —  — 
Section 475 Adj 452,563,059  4,008,085  99,247,829  —  — 
Capitalized Costs 1,803,697  11,276  279,227  —  — 
Misc Cap Costs 44,460  1,871  46,331  —  — 
Prepaid Expenses 610,558  788,635  1,083,499  —  — 
Income Tax Adjustment 6,266,989  —  —  —  — 
TOTAL $562,842,228  $88,357,416  $169,202,929  $—  $— 
ADJUSTMENTS
DEBITS CREDITS
ACCOUNT CREDITED AMOUNT ACCOUNT DEBITED AMOUNT BALANCE AT END OF YEAR
Deferred Fuel $—  $—  $35,731,088 
Reg Asset Covid 19 —  —  2,457,384 
Reg Asset-Securitization —  —  29,078,315 
Prepaid Expenses —  —  5,031,060 
Minimum Pension Liability 190  6,567,283  —  34,978,599 
Bond Reacquisition Loss —  —  2,711,242 
Section 475 Adj —  —  357,323,315 
Capitalized Costs —  —  1,535,746 
Misc Cap Costs —  —  — 
Prepaid Expenses —  —  315,694 
Income Tax Adjustment —  182.3/254 112,317  6,379,306 
TOTAL $6,567,283  $112,317  $475,541,749 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
Income Taxes
237,562,856
9,936,416
227,626,440
2
Vegetation Management Rider Over-Recovery MPSC Docket No. 2018-UN-205
2,246,105
2,246,105
3
MISO Financial Transmission Rights Mark-to-Market
229,578
229,578
4
Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132
7,173,150
7,173,150
5
MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132
4,767,583
3,629,243
1,138,340
6
Power Management Rider Over-Recovery MPSC Docket No. 2014-UN-132
20,822,563
30,293,833
51,116,396
7
Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620
15,114,053
15,114,053
8
Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198
1,435,474
2,295,100
3,730,574
41 TOTAL
286,875,679
35,852,862
35,064,616
286,087,433


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
651,455,098
578,258,495
5,608,027
5,568,055
383,643
383,468
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
(a)
508,995,814
(d)
439,949,537
4,575,185
4,468,879
66,822
66,343
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
182,270,134
150,697,534
2,352,058
2,297,663
4,021
4,006
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
17,343,984
15,770,896
74,556
77,286
426
429
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
35,517,385
30,476,742
338,580
333,052
4,761
4,741
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
1,395,582,415
1,215,153,204
12,948,406
12,744,935
459,673
458,987
11
SalesForResaleAbstract
(447) Sales for Resale
165,984,871
124,631,972
2,913,988
4,363,569
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
1,561,567,286
1,339,785,176
15,862,394
17,108,504
459,673
458,987
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
1,561,567,286
1,339,785,176
15,862,394
17,108,504
459,673
458,987
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
6,732,561
5,785,312
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(b)
1,483,539
(e)
2,551,400
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
11,270,862
11,201,890
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(c)
16,745,617
(f)
3,389,694
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
51,889,728
40,263,484
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
6,177,413
10,148,719
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
60,808,486
66,561,111
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
1,622,375,772
1,406,346,287
Line12, column (b) includes $
of unbilled revenues.
Line12, column (d) includes
MWH relating to unbilled revenues


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(b) Concept: MiscellaneousServiceRevenues
Revenues from return charges and connection fee.
(c) Concept: OtherElectricRevenue
Other Electric Revenues include:

Retail bill credits - System Energy Settlement ($36,667,440)
Unbilled Revenue - Includes 92,709 MWH 17,439,475 
MISO Mkt Sch 11 Wholesale Dist 1,051,487 
Ouachita Transmission Upgrade Reimbursement 970,860 
Utility-owned Distributed Generation revenue 421,521 
Solar Service Fee 23,611 
Deposit Alternative Plan 13,669 
MS Department of Revenue vendor discount 1,200 
Total ($16,745,617)
(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.
(e) Concept: MiscellaneousServiceRevenues
Revenues from return charges and connection fee.
(f) Concept: OtherElectricRevenue
Other Electric Revenues include:
MISO Mkt Sch 11 Wholesale Dist $1,018,414 
Ouachita Transmission Upgrade Reimbursement 970,860 
Grid Modernization 2,866 
MS Department of Revenue vendor discount 1,200 
Third Party Sales of Inventory (3,322)
Choctaw Interim Recovery Rider (1,899,050)
Unbilled Revenue - Includes (102,252) MWH (3,480,662)
Total ($3,389,694)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
MISO Sch 1 Sched/Sys Ctrl/Disp
159,258
319,505
521,461
692,773
2
MISO Sch 2 Reactive
904,436
2,433,414
4,160,570
5,484,640
46
TOTAL
1,063,694
2,752,919
4,682,031
6,177,413


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
RS-39C Residential Service
3,890,396
455,287,113
279,913
13,899
0.1170
2
RS-39W Residential Water Heating Service
1,684,299
186,045,601
102,714
16,398
0.1105
3
PAL-17 Private Area Lighting
29,517
8,386,392
831
35,520
0.2841
4
UFL-16 Urban Flood Lighting
6
1,023
1
6,000
0.1705
5
RFL-16 Rural Flood Lighting
2
358
1
2,000
0.1790
6
DSL-16 Directional Security  Lighting
1,557
455,382
64
24,328
0.2925
7
LED-2 LED Street and Area  Lighting
2,250
1,279,320
119
18,908
0.5686
8
GS-299 General Lighting and Power
91
9
IPS-26 Irrigation Pumping Power
41 TOTAL Billed Residential Sales
5,608,027
(a)
651,455,098
383,643
14,618
0.1162
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
5,608,027
651,455,098
383,643
14,618
0.1162


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled
Residential
Includes fuel adjustment revenues of:
RS-39C Residential Service ($35,002,553)
RS-39W Residential Water Heating Service (15,569,039)
PAL-17 Private Area Lighting (266,549)
UFL-16 Urban Flood Lighting (59)
RFL-16 Rural Flood Lighting (16)
DSL-16 Directional Security Lighting (14,022)
GS-299 General Lighting and Power 10 
HL-21 Public Highway & Park Lighting — 
LED-2 LED Street and Area Lighting (19,962)
TOTAL RESIDENTIAL FUEL ADJUSTMENT REVENUES ($50,872,190)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 General Lighting and Power
2,440,459
316,311,733
64,402
37,894
0.1296
2
HLF-7 High Load Factor
1,151,111
97,161,818
311
3,701,322
0.0844
3
PAL-17 Private Area Lighting
14,621
4,433,770
858
17,041
0.3032
4
UFL-16 Urban Flood Lighting
159
27,468
18
8,833
0.1728
5
RFL-16 Rural Flood Lighting
7
1,470
0.2100
6
DSL-16 Directional Security  Lighting
32,589
7,190,116
614
53,077
0.2206
7
LED-2 LED Street and Area  Lighting
15,666
5,341,301
205
76,420
0.3409
8
B-34 Intermediate General Service
344,504
35,743,267
277
1,243,697
0.1038
9
SL-37 Municipal Street Lighting
26,597
4
10
TF-23 Traffic Control Signals
2
171
0.0855
11
FAYETTE
406
17,032
1
406,000
0.0420
12
IPS-26 Irrigation Pumping Power
13
GS-299 MS Gen. Lghtg & Pwr Muni. Service
14
QF-18
15
Miscellaneous
7,952
87
16
ALGS-10 Alternate Large General Service
409,323
28,476,236
6
68,220,500
0.0696
17
MP-22 Municipal Pumping Power Service
18
GLP-17 Gen. Lghtg. & Pwr Redist. & Res.
1,422
166,339
1
1,422,000
0.1170
19
C-29 Large General Service
164,558
14,048,453
15
10,970,533
0.0854
20
SWH-20 Gen. Space and Water Heating Serv.
364
42,653
18
20,222
0.1172
21
RS-39C Residential Service
2
220
5
400
0.1100
22
RS-39W Residential Water Heating Service
41 TOTAL Billed Small or Commercial
4,575,185
(a)
508,995,814
66,822
68,468
0.1113
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43 TOTAL Small or Commercial
4,575,185
(b)
508,995,814
66,822
68,468
0.1113


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled
Commercial
Includes Fuel Adjustment Revenues of:
GS-299 General Lighting and Power ($22,011,888)
B-34 Intermediate General Service (3,221,419)
C-29 Large General Service (1,477,225)
ALGS-10 Alternate Large General Service (3,634,733)
HLF-7 High Load Factor General Service (10,476,983)
FAYETTE — 
GLP-17 Gen. Lghtg. & Pwr for Redist. & Res. (12,792)
DSL-16 Directional Security Lighting (298,230)
SWH-20 Gen. Space and Water Heating Serv. (3,264)
PAL-17 Private Area Lighting ($134,760)
UFL-16 Urban Flood Lighting (1,025)
RFL-16 Rural Flood Lighting (65)
RS-39C Residential Service 53 
RS-39W Residential Water Heating Service — 
TF-23 Traffic Control Signal 34 
MP-22 Municipal Pumping Power — 
IPS-26 Irrigation Pumping Power — 
HL-21 Public Highway & Park Lighting — 
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting (138,877)
SE-29 State Institutions Service — 
GS-299 MS Gen L&P Muni Service — 
GS-298X Gen L&P TOU — 
TOTAL COMMERCIAL FUEL ADJUSTMENT REVENUES ($41,411,174)
(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue
Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 General Lighting and Power
137,736
17,895,287
2,178
63,240
0.1299
2
HLF-7 High Load Factor
576,519
47,795,836
78
7,391,269
0.0829
3
PAL-17 Private Area Lighting
523
145,795
21
24,905
0.2788
4
UFL-16 Urban Flood Lighting
7
1,389
1
7,000
0.1984
5
RFL-16 Rural Flood Lighting
2
358
0.1790
6
DSL-16 Directional Security  Lighting
2,160
452,173
19
113,684
0.2093
7
LED-2 LED Street and Area  Lighting
577
174,077
3
192,333
0.3017
8
B-34 Intermediate General Service
163,592
18,059,994
88
1,859,000
0.1104
9
C-29 Large General Service
235,220
21,263,382
29
8,111,034
0.0904
10
IPS-26 Irrigation Pumping Power
19,975
4,049,714
1,531
13,047
0.2027
11
IP-33 Ice Manufacturing Plant Power
225
26,342
1
225,000
0.1171
12
ALGS-10 / Other
713,779
52,616,528
16
44,611,188
0.0737
13
Contract Rates
498,678
19,372,061
4
124,669,500
0.0388
14
GS-298X
3,065
417,198
52
58,942
0.1361
15
GS-299 MS Gen. Lghtg & Pwr Muni. Service
0
16
RS-39C Residential Service
0
41 TOTAL Billed Large (or Ind.) Sales
2,352,058
(a)
182,270,134
4,021
584,944
0.0775
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43 TOTAL Large (or Ind.)
2,352,058
182,270,134
4,021
584,944
0.0775


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled
Industrial
Includes Fuel Adjustment Revenues of:
GS-299 General Lighting and Power ($1,256,547)
B-34 Intermediate General Service (1,466,004)
C-29 Large General Service (2,106,617)
ALGS-10 / Other (2,519,896)
HLF-7 High Load Factor General Service (5,159,720)
DSL-16 Directional Security Lighting (19,845)
IPS-26 Irrigation Pumping Power (167,547)
IP-33 Ice Manufacturing Plant Power (1,979)
PAL-17 Private Area Lighting Service (4,722)
UFL-16 Urban Flood Lighting Service ($65)
RFL-16 Rural Flood Lighting Service (16)
SL-37 Municipal Street Lighting — 
LED-2 LED Street and Area Lighting (5,107)
GS-299 MS Gen L&P Muni Service — 
GS-298X Gen L&P TOU (29,402)
RS-39W Residential Water Heating Service — 
TOTAL INDUSTRIAL FUEL ADJUSTMENT REVENUES ($12,737,467)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41 TOTAL Billed Commercial and Industrial Sales
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
SL-37 Municipal Street Lighting
58,222
15,476,440
136
428,103
0.2658
2
HL-21 Public Highway & Park Lighting
12,223
1,279,069
86
142,128
0.1046
3
TF-23 Traffic Control Signals
4,033
550,016
195
20,682
0.1364
4
LED-2 LED Street and Area  Lighting
78
38,459
9
8,667
0.4931
41 TOTAL Billed Public Street and Highway Lighting
74,556
(a)
17,343,984
426
175,014
0.2326
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
74,556
17,343,984
426
175,014
0.2326


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled
Public Street and Highway Lighting
Includes Fuel Adjustment Revenues of:
TF-23 Traffic Control Signals ($36,913)
HL-21 Public Highway & Park Lighting (109,543)
SL-37 Municipal Street Lighting (533,780)
DSL-16 Directional Security Lighting — 
PAL-17 Private Area Lighting Service — 
LED-2 LED Street and Area Lighting (706)
TOTAL PUBLIC STREET AND HIGHWAY LIGHTING FUEL ADJUSTMENT REVENUES ($680,942)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
GS-299 MS Gen. Lghtg & Pwr Muni. Service
179,426
19,027,993
2,706
66,307
0.1060
2
MP-22 Municipal Pumping Power Service
86,802
9,908,562
1,960
44,287
0.1142
3
SE-29 State Institutions
69,210
5,829,525
8
8,651,250
0.0842
4
GS-299 General Lighting and Power
1
493
0.4930
5
SL-37 Municipal Street Lighting
496
6
PAL-17 Private Area Lighting
483
135,381
19
25,421
0.2803
7
DSL-16 Directional Security  Lighting
2,283
491,589
60
38,050
0.2153
8
LED-2 LED Street and Area  Lighting
372
123,642
8
46,500
0.3324
9
UFL-16 Urban Flood Lighting
5
690
0.1380
41 TOTAL Billed Other Sales to Public Authorities
338,580
(a)
35,517,385
4,761
71,115
0.1049
42 TOTAL Unbilled Rev. (See Instr. 6)
43 TOTAL
338,580
35,517,385
4,761
71,115
0.1049


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled
Other Sales to Public Authorities
Includes Fuel Adjustment Revenues of:
GS-299 MS Gen. Lghtg & Pwr Muni.Service ($1,635,908)
MP-22 Municipal Pumping Power Service (815,704)
SE-29 State Institutions (616,201)
DSL-16 Directional Security Lighting (20,829)
PAL-17 Private Area Lighting (4,424)
UFL-16 Urban Flood Lighting (41)
HL-21 Public Highway & Park Ltg — 
GS-299 General Lighting and Power 28 
RS-39W Residential Water Heating Service — 
LED-2 LED Street and Area Lighting (3,390)
B-34 Intermediate General Service — 
TOTAL OTHER SALES TO PUBLIC AUTH FUEL ADJ REV ($3,096,469)

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
12,948,406
1,395,582,415
459,673
28,169
0.1078
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43 TOTAL - All Accounts
12,948,406
1,395,582,415
459,673
28,169
0.1078


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

    AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
Midcontinent ISO, Inc.
2,913,988
442
157,686,581
(a)
8,297,848
165,984,871
15
Subtotal - RQ
16
Subtotal-Non-RQ
2,913,988
442
157,686,581
8,297,848
165,984,871
17 Total
2,913,988
442
157,686,581
8,297,848
165,984,871


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale
MISO Ancillary $559,119 
MISO Residual Load 305,798 
MISO Uplift 7,432,931 
Total $8,297,848 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
3,455,138
4,544,995
5
FuelSteamPowerGeneration
(501) Fuel
(a)
509,262,621
(b)
318,054,549
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
2,757,819
2,278,994
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
463,557
603,100
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
7,820,072
8,181,881
11
RentsSteamPowerGeneration
(507) Rents
143,513
21,732
12
Allowances
(509) Allowances
9,363
26,384
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
523,912,083
333,711,635
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
444,077
500,249
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
936,689
745,604
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
8,388,292
7,965,946
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
3,498,961
3,517,853
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
18,127,326
19,129,509
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
31,395,345
31,859,161
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
555,307,428
365,570,796
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
900,712
994,428
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
1,133,250
809,873
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
9,750,002
8,944,873
66
RentsOtherPowerGeneration
(550) Rents
133,040
92,131
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
11,917,004
10,841,305
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
25,262
37,459
70
MaintenanceOfStructures
(552) Maintenance of Structures
386,288
341,996
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
7,583,103
5,790,155
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
890,140
526,849
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
8,884,793
6,696,459
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
20,801,797
17,537,764
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
322,642,544
297,967,897
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
0
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
743,341
676,994
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
256,322,872
136,362,952
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
67,063,013
162,281,939
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
643,172,238
545,390,499
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
2,434,527
2,694,179
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
2,191,750
2,152,248
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
41,042
45,110
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
4,155,039
4,182,192
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
373,256
333,098
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
931
2,910
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
481,753
552,456
93
StationExpensesTransmissionExpense
(562) Station Expenses
188,668
209,844
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
877,982
812,538
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
5,848,743
7,731,993
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
775,495
907,443
98
RentsTransmissionElectricExpense
(567) Rents
686,509
686,521
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
18,055,695
20,310,532
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
2,913,658
2,473,668
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
99,294
235,382
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
6,354
2,433
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
101,512
54,133
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
2,684,821
1,921,776
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
4,206,079
3,647,894
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
54,794
64,442
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
10,066,512
8,399,728
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
28,122,207
28,710,260
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
2,533,399
2,673,202
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
2,533,399
2,673,202
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
2,533,399
2,673,202
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
13,676,083
11,477,640
135
LoadDispatching
(581) Load Dispatching
170,777
148,665
136
StationExpensesDistribution
(582) Station Expenses
237,764
185,661
137
OverheadLineExpenses
(583) Overhead Line Expenses
1,049,452
1,037,680
138
UndergroundLineExpenses
(584) Underground Line Expenses
2,096,055
1,720,063
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
193,137
155,799
140
MeterExpenses
(586) Meter Expenses
2,188,029
2,075,232
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
982,290
779,122
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
4,425,430
3,716,345
143
RentsDistributionExpense
(589) Rents
2,517,249
2,454,909
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
27,536,266
23,751,116
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
1,684,887
974,260
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
708,532
714,007
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
1,436,426
1,052,921
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
34,790,739
29,873,238
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
1,704,652
1,143,003
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
334,752
391,239
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
776,259
741,910
153
MaintenanceOfMeters
(597) Maintenance of Meters
97,563
42,883
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
1,598,919
1,480,506
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
43,132,729
36,413,967
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
70,668,995
60,165,083
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
221,798
208,362
160
MeterReadingExpenses
(902) Meter Reading Expenses
949,985
3,178,288
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
21,148,904
19,322,183
162
UncollectibleAccounts
(904) Uncollectible Accounts
6,903,130
3,683,745
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
81,811
103,213
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
29,305,628
26,495,791
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
698,182
354,409
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
6,807,096
3,822,364
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
1,008,047
811,223
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
1,458,413
1,512,884
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
9,971,738
6,500,880
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
1,083
505
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
764,224
229,639
176
AdvertisingExpenses
(913) Advertising Expenses
1,012,696
898,185
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
179,051
56,519
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
1,957,054
1,184,848
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
31,763,394
31,101,577
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
2,598,364
1,363,669
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
184
OutsideServicesEmployed
(923) Outside Services Employed
16,990,553
17,097,225
185
PropertyInsurance
(924) Property Insurance
17,448,846
23,014,869
186
InjuriesAndDamages
(925) Injuries and Damages
3,129,102
2,148,906
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
25,412,945
26,586,368
188
FranchiseRequirements
(927) Franchise Requirements
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
4,316,685
3,071,197
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
961,113
1,019,129
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
4,626,144
3,932,845
193
RentsAdministrativeAndGeneralExpense
(931) Rents
538,182
501,708
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
107,785,328
109,837,493
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
1,319,622
1,322,449
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
109,104,950
111,159,942
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
894,836,209
782,280,505


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration
Includes ($70,877,422) relating to certain gas hedging activities.
(b) Concept: FuelSteamPowerGeneration
Includes ($21,499,986) relating to certain gas hedging activities.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
Energy System Power Pool
2
(a)
System Energy Resources, Inc.
2,553,889
201,152,608
16,571,258
(c)
40,147,986
177,575,880
3
(b)
Entergy Arkansas, LLC
537,639
43,241,977
3,488,716
46,730,693
4
Terra Miss Nitrogen
203
15,733
15,733
5
CF Industries Nitrogen, LLC
2,372
70,911
70,911
6
Midcontinent ISO, Inc.
1,574,692
48,062
116,314,654
(d)
11,148,762
105,213,954
7
Small Residential Generation
841
44,920
44,920
8
EDF Trading North America, LLC
(e)
30,106
30,106
9
Rainbow Energy Marketing Corp
55,980
55,980
10
Southwest Mississippi Electric Power
(f)
25,660
25,660
11
APX
(g)
250
250
12
Sunflower
(h)
7,061,331
7,061,331
15 TOTAL
4,669,636
0
0
0
244,498,627
136,506,192
58,362,275
322,642,544


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges from the Grand Gulf Nuclear Power Plant.
(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Energy and capacity charges associated with MSS-4.
(c) Concept: OtherChargesOfPurchasedPower
Represents ($35,278,623) for deferral on over/under recovery under the Grand Gulf Rider and ($4,869,363) for the turnaround of the Grand Gulf Accelerated Recovery Tariff approved by the FERC that provided for the acceleration of Entergy Arkansas's and Entergy Mississippi's Grand Gulf purchased power obligations with System Energy Resources.
(d) Concept: OtherChargesOfPurchasedPower
CHARGES
MISO Ancillary $652,818 
MISO Congestion (10,430,615)
MISO Losses (3,814,326)
MISO Residual Load 308,157 
MISO Uplift 1,966,459 
MISO Administration 168,745 
Total Other Purchases from MISO ($11,148,762)
(e) Concept: OtherChargesOfPurchasedPower
Related to the sale of Entergy Mississippi's Auction Revenue Rights allocated to Entergy Mississippi as part of its participation in MISO.
(f) Concept: OtherChargesOfPurchasedPower
Temporary service to Entergy Mississippi's  retail customers.
(g) Concept: OtherChargesOfPurchasedPower
Renewal Energy Credit registration fee
(h) Concept: OtherChargesOfPurchasedPower
MISO revenue associated with Sunflower was retained at Entergy Mississippi during the test period per the regulatory orders.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
MISO
Various
Various
Various
Various
51,889,728
51,889,728
35 TOTAL
0
0
0
51,889,728
51,889,728


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
Midcontinent Independent System Operator Inc
(a)
5,799,581
(b)
49,162
5,848,743
TOTAL
0
0
5,799,581
0
49,162
5,848,743


FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers
The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Mississippi incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Mississippi and billed the entity for such service.
(b) Concept: OtherChargesTransmissionOfElectricityByOthers
Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
470,784
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
347,271
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
5% surcharge on regulated billings to non-regulated affiliates
190,080
7
Directors meetings and expenses
80,113
8
Section 263A research - tax services
15,701
9
System aircraft
2,884
10
Corporate purchasing card rebates
77,110
11
IT hardware applications/service contracts
4,018,679
12
Mobile device services
6,007
13
Other
48,105
46
MiscellaneousGeneralExpenses
TOTAL
4,626,144


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
23,210,109
23,210,109
2
Steam Production Plant
31,423,332
11,486
31,434,818
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
27,571,735
27,571,735
7
Transmission Plant
43,567,090
43,567,090
8
Distribution Plant
92,602,281
92,602,281
9
Regional Transmission and Market Operation
10
General Plant
(a)
23,934,705
23,934,705
11
Common Plant-Electric
12
TOTAL
219,099,143
11,486
23,210,109
242,320,738
B. Basis for Amortization Charges
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Includes $3,775,889 of service company depreciation billing allocations.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Other expenses incurred in connection wiht various filings before the FERC
54,791
54,791
Electric
54,791
2
Other expenses incurred in connection with MISO and other transmission related FERC dockets
75,488
75,488
Electric
75,488
3
MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis
1,398,507
1,398,507
Electric
1,398,507
4
MPSC Docket No. 2008-UN-381 - Power Management Rider Expense
283
283
Electric
283
5
MPSC Docket No. 2009-UN-388 - Attorney General Litigation
67,082
67,082
291,331
Electric
67,082
224,249
6
MPSC Docket No. 2018-UN-205 - EML Formula Rate Plan
308,996
308,996
Electric
308,996
7
MPSC Docket No. 2010-AD-2 - MS EE Comprehensive Portfolio Program
Electric
8
Other expenses incurred in connection with various filings before the MPSC
2,256,271
2,256,271
Electric
2,256,271
9
MPSC Docket No. 2008-UN-388 - EML Formula Rate Plan
128
128
Electric
128
10
MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan
155,139
155,139
Electic
155,139
46
TOTAL
4,316,685
4,316,685
291,331
4,249,603
67,082
224,249


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
A(3) B(4)
Advanced meters
64,889
194
65,083
2
A(3)
Distribution Automation
3,865
3,865
3
B(4)
Transmission University Research
10,723
10,723
4
B(4)
Environmental Research
35,350
35,350
5
B(1)
EPRI dues
70,020
70,020
6
B(1)
EPRI 1
80,132
80,132
7
B(1)
EPRI 2
306,045
306,045
8
B(1)
EPRI 3
79,941
79,941
9
B(2)
Edison Electric Institute
248,573
248,573
10
B(4)
SERC
523,657
523,657
11
B(4)
Smart Electric Power Alliance
540
540


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
11,718,586
4
SalariesAndWagesElectricOperationTransmission
Transmission
540,740
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
7,554,362
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
2,760,176
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
1,812,893
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
5,517,199
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
29,903,956
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
7,704,165
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
2,023,098
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
6,757,321
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
211,904
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
16,696,488
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
19,422,751
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
2,563,838
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
14,311,683
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
2,760,176
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
1,812,893
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
5,729,103
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
46,600,444
46,600,444
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
46,600,444
46,600,444
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
38,210,782
38,210,782
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
38,210,782
38,210,782
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
2,495,265
2,495,265
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
2,495,265
2,495,265
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
PRELIMINARY SURVEY & INVTG CH
4,571
4,571
80
SalariesAndWagesOtherAccountsDescription
Stores Expense Undistributed (Account 163)
2,052,477
2,052,477
81
SalariesAndWagesOtherAccountsDescription
Miscellaneous Current and Accrued Assets (Account 174)
149,818
149,818
82
SalariesAndWagesOtherAccountsDescription
Clearing Accounts (Account 184)
2,874,628
2,874,628
83
SalariesAndWagesOtherAccountsDescription
Miscellaneous Deferred Debits (Account 186)
402,000
402,000
84
SalariesAndWagesOtherAccountsDescription
Accumulated Provisions for Property Insurance (Account 2281)
4,253,818
4,253,818
85
SalariesAndWagesOtherAccountsDescription
Accumulated Miscellaneous Operating Provisions (Account 2284)
3,707
3,707
86
SalariesAndWagesOtherAccountsDescription
Civil, Political, and Related Expenses (Account 4264)
696,762
696,762
87
SalariesAndWagesOtherAccountsDescription
Other Deductions (Account 4265)
28,146
28,146
88
SalariesAndWagesOtherAccountsDescription
EMPLOYMENT TAXES (Account 40811)
39,346
39,346
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
10,505,273
10,505,273
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
97,811,764
(a)
97,811,764


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: SalariesAndWagesGeneralExpense
The following payroll charges from Entergy Services are not included in this schedule and are included in the Electric O&M schedule (pages 320-323) only:

CHARGES
Production: $5,615,253 
Transmission: $4,386,845 
Distribution: $2,774,361 
Customer Accts: $2,328,164 
Customer Service: $390,965 
Sales: $15,263 
Administrative & General: $24,127,456 

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
13,558,693
56,586,265
88,913,795
116,314,654
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
19,190,316
60,030,274
115,600,054
157,686,581
4 Transmission Rights
5 Ancillary Services
6 Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL
5,631,623
3,444,009
26,686,259
41,371,927


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
692,773
2
Reactive Supply and Voltage
5,420,512
5,484,640
3
Regulation and Frequency Response
4
Energy Imbalance
5
Operating Reserve - Spinning
6
Operating Reserve - Supplement
7
Other
8
Total (Lines 1 thru 7)
5,420,512
(a)
6,177,413


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount
Entergy Mississippi is a transmission owning member of Midwest Independent Transmission System Operator (MISO) RTO. Entergy Mississippi does not purchase or sell transmission services or ancillary services directly. Instead, Entergy Mississippi receives revenues and incurs expenses from transmission services and ancillary sold by MISO. MISO distributes the revenue that it receives to the transmission owner and the transmission owner pays MISO for the related expenses incurred.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: Entergy Mississippi, LLC
1
January
2,796
21
10
2,107
689
2
February
2,724
4
20
2,045
679
3
March
2,408
13
9
1,823
585
4
Total for Quarter 1
5,975
1,953
0
0
0
0
5
April
2,327
22
17
1,841
486
6
May
3,157
12
17
2,453
704
7
June
3,677
23
16
2,814
863
8
Total for Quarter 2
7,108
2,053
0
0
0
0
9
July
3,824
12
17
2,957
867
10
August
3,507
8
16
2,711
796
11
September
3,339
21
16
2,604
735
12
Total for Quarter 3
8,272
2,398
0
0
0
0
13
October
2,339
12
17
1,794
545
14
November
2,427
18
8
1,805
622
15
December
3,166
23
20
2,348
818
16
Total for Quarter 4
5,947
1,985
0
0
0
0
17
Total
27,302
8,389
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: 0
1
January
0
2
February
0
3
March
0
4
Total for Quarter 1
0
0
0
0
0
0
5
April
0
6
May
0
7
June
0
8
Total for Quarter 2
0
0
0
0
0
0
9
July
0
10
August
0
11
September
0
12
Total for Quarter 3
0
0
0
0
0
0
13
October
0
14
November
0
15
December
0
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-04-13
Year/Period of Report

End of:
2022
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
12,948,406
3
Steam
12,016,967
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
2,913,988
5
Hydro-Conventional
25
Energy Furnished Without Charge
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
8,174
7
Other
1,600
27
Total Energy Losses
817,635
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
12,018,567
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
16,688,203
10
Purchases (other than for Energy Storage)
4,669,636
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
0
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
16,688,203


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: Entergy Mississippi, LLC
29
January
1,364,783
191,895
2,173
21
10
30
February
1,156,822
154,377
2,134
4
20
31
March
1,152,734
188,446
1,791
12
11
32
April
1,132,459
225,940
1,785
22
17
33
May
1,358,681
178,429
2,538
12
17
34
June
1,663,502
272,758
2,934
23
16
35
July
1,718,647
202,055
2,938
21
16
36
August
1,648,687
256,296
2,795
15
17
37
September
1,670,829
477,469
2,751
21
16
38
October
993,646
23,939
1,931
12
17
39
November
1,155,284
171,617
1,919
18
9
40
December
1,672,129
570,767
2,414
23
20
41
Total
16,688,203
2,913,988


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
Attala
Plant Name:
Baxter Wilson
Plant Name:
Choctaw
Plant Name:
Gerald Andrus
Plant Name:
Hinds
Plant Name:
(a)
Independence
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
Gas Turbine
Steam
Combined Cycle
Steam
Gas Turbine
Steam
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
Outdoor Boiler
Outdoor
Outdoor Boiler
Outdoor Boiler
3
YearPlantOriginallyConstructed
Year Originally Constructed
2001
1966
2019
1975
2001
1983
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
2001
1971
2019
1975
2001
1984
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
551
545
899
781
600
1,800
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
513
513
916
709
556
1,670
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
7,395
1,356
5,492
2,347
7,867
10,864
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
501
559
848
750
526
1,680
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
458
494
797
707
481
1,663
11
PlantAverageNumberOfEmployees
Average Number of Employees
27
14
30
31
36
51
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
3,346,428,070
308,824,587
3,414,744,819
755,886,670
3,069,821,654
1,121,261,252
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
128,931
359,115
2,761,498
331,301
1,362,657
1,068,160
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
17,575,549
12,877,536
208,947,378
31,061,259
101,300,863
22,319,193
15
CostOfEquipmentSteamProduction
Equipment Costs
120,980,576
86,360,018
292,323,491
171,059,949
232,454,967
258,828,252
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
0
136,135
0
0
1,507,847
17
CostOfPlant
Total cost (total 13 thru 20)
138,685,056
99,732,804
504,032,367
202,452,509
335,118,487
283,723,452
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
252
183
561
259
558
158
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
877,686
407,039
436,540
1,495,613
551,713
587,259
20
FuelSteamPowerGeneration
Fuel
148,818,534
22,741,289
181,524,950
58,518,748
135,635,657
32,902,331
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
0
0
0
0
22
SteamExpensesSteamPowerGeneration
Steam Expenses
26,548
405,617
44,933
1,872,033
27,871
380,817
23
SteamFromOtherSources
Steam From Other Sources
0
0
0
24
SteamTransferredCredit
Steam Transferred (Cr)
0
0
0
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
937,290
188,407
2,666
35,536
199,189
233,719
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
5,053,650
1,202,966
1,024,367
2,880,568
5,501,278
1,705,625
27
RentsSteamPowerGeneration
Rents
125,326
27,362
10,697
82,119
20,669
10,380
28
Allowances
Allowances
371
244
441
4,745
332
3,230
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
53,505
32,342
48,960
257,096
31,051
46,385
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
185,982
83,488
222
596,466
200,576
256,243
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
4,023
188,697
6,810
4,833,151
4,224
3,351,387
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
3,426,835
52,945
8,075
1,266,781
4,148,555
2,178,873
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
464,063
300,884
14,269,659
573,200
1,073,147
2,336,513
34
PowerProductionExpensesSteamPower
Total Production Expenses
159,973,813
25,631,280
197,378,320
72,416,056
147,394,262
43,992,762
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
0.0478
0.0830
0.0578
0.0958
0.0480
0.0392
35
FuelKindAxis
Plant Name
Attala
Baxter Wilson
Baxter Wilson
Choctaw
Gerald Andrus
Gerald Andrus
Hinds
Independence
Independence
36
FuelKind
Fuel Kind
Gas
Gas
Oil
Gas
Gas
Oil
Gas
Coal
Oil
37
FuelUnit
Fuel Unit
Mcf
Mcf
bbl
Mcf
Mcf
bbl
Mcf
T
bbl
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
22,295,635
3,178,908
534
22,508,906
8,229,742
1,424
20,608,570
70,150
7,285
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
1,065,041
1,083,805
140,476
1,070,263
1,034,535
140,476
1,067,915
86,840
140,476
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
7
7
376
8
7
253
7
455
134
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
6
7
64
8
7
43
6
3
23
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation
7,096
11,166
7,055
11,275
7,169
10,904


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: PlantName
Indepedence - Reflects Entergy Mississippi's 25% ownership interest in Independence Units 1 and 2.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net kWh


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
25
WaterForPower
Water for Power
26
PumpedStorageExpenses
Pumped Storage Expenses
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
29
RentsPumpedStoragePlant
Rents
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))
0


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Project Costs included in
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
9,879,694
5,258,880
152,890
15,291,464
2
BAXTER WILSON
GRAND GULF 500 - [5620]
500
500
21.46
0.00
1
954 ACSR
3
BAXTER WILSON
PERRYVILLE 500 - [5200]
500
500
1.46
0.00
1
3070 AACSR
4
BAXTER WILSON
RAY BRASWELL 500 - [6880]
500
500
35.54
5.44
2
954 ACSR
5
BOGALUSA 500
FRANKLIN EHV - [5521]
500
500
51.38
0.00
1
954 ACSR
6
CHOCTAW
FRENCH CAMP 500 - [5014]
500
500
0.81
0.00
1
954 ACSR
7
FRANKLIN
GRAND GULF 500 - [5640]
500
500
43.46
0.00
1
954 ACSR
8
FRANKLIN
RAY BRASWELL 500 - [6980]
500
500
58.30
0.00
1
954 ACSR
9
MCADAMS
LAKEOVER 500 - [6960]
500
500
57.44
0.00
1
954 ACSR
10
MCKNIGHT
FRANKLIN 500 - [6980]
500
500
38.36
0.00
1
954 ACSR
11
RAY BRASWELL
LAKEOVER 500 - [7130]
500
500
22.50
3.35
2
954 ACSR
12
WOLF CREEK
CHOCTAW 500 - [5015]
500
500
0.11
0.00
1
954 ACSR
13
WOLF CREEK
FRENCH CAMP 500 - [6960]
500
500
0.83
0.00
1
954 ACSR
14
WOLF CREEK
MCADAMS 500 - [6960]
500
500
24.21
0.00
1
954 ACSR
15
Total 500kV
5,483,196
63,221,618
68,704,814
16
CATLETT
YANDELL RD 230 - [2343]
230
230
12.40
2.29
2
1272 ACSR
17
CATLETT
SOUTH CANTON 230 - [2392]
230
230
3.60
0.00
1
1272 ACSR
18
CATLETT
TINNIN RD 230 - [5112]
230
230
25.29
2.30
2
1272 ACSR
19
FREEPORT
HORN LAKE 230 - [5942]
230
230
3.81
0.00
1
954 ACSR
20
GERALD ANDRUS
LAKE VILLAGE BAGBY 230 - [5540]
230
230
3.59
0.00
1
1534.4 ACAR
21
GERALD ANDRUS
INDIANOLA 230 - [5580]
230
230
33.67
8.38
2
1272 ACSR
22
GETWELL
BYHALA 230 - [2341]
230
230
5.88
0.00
1
1272 ACSR
23
GETWELL
TWINKLETOWN 230 - [5007]
230
230
20.54
1.40
2
1272 ACSR
24
HORN LAKE
GETWELL 230 - [6186]
230
230
8.57
4.77
2
1272 ACSR
25
INDIANOLA
TILLATOBA 230 - [6020]
230
230
56.36
0.00
1
1272 ACSR
26
LAKEOVER
HINDS2 230 - [6666]
230
230
0.34
0.00
1
1272 ACSR
27
LAKEOVER
LUCKNEY 230 - [2311]
230
230
22.80
8.40
2
1272 ACSR
28
LAKEOVER
YANDELL RD 230 - [2335]
230
230
18.30
10.16
2
1272 ACSR
29
LAKEOVER
REX BROWN (EAST) 230 - [6184]
230
230
1.74
1.56
2
1272 ACSR
30
LAKEOVER
REX BROWN (WEST) 230 - [6183]
230
230
1.75
1.57
2
1272 ACSR
31
LUCKNEY
RANKIN 230 - [6298]
230
230
13.47
0.00
1
1272 ACSR
32
MCADAMS
ATTALA 230 - [6415]
230
230
1.17
0.00
1
1272 ACSR
33
MCADAMS
INDIANOLA 230 - [6410]
230
230
67.53
0.00
1
1272 ACSR
34
MCADAMS
PICKENS 230 - [6416]
230
230
16.18
0.00
1
954 ACSR
35
MOON LAKE
BATESVILLE 230 - [6300]
230
230
33.01
0.00
1
1272 ACSR
36
RAY BRASWELL
S JACKSON 230 - [7370]
230
230
9.45
9.22
2
1272 ACSR
37
RAY BRASWELL
SOUTH JACKSON 230 - [7375]
230
230
13.53
10.95
2
1272 ACSR
38
RAY BRASWELL
NORREL 230 - [2340]
230
230
7.36
3.21
2
1272 ACSR
39
RAY BRASWEL
REX BROWN 230 - [7100]
230
230
9.18
0.00
1
1272 ACSS
40
RITCHIE
MOON LAKE 230 - [6320]
230
230
6.80
0.00
1
1947.5 ACSR
41
RITCHIE
TUNICA 230 - [7490]
230
230
21.36
0.00
1
1947.5 ACSR
42
SOUTH CANTON
RAGSDALE 230 LN 1 - [5271]
230
230
1.53
1.29
2
1272 ACSR
43
SOUTH CANTON
RAGSDALE 230 LN 2 - [5271]
230
230
1.55
1.29
2
1272 ACSR
44
SOUTH CANTON
YANDEL RD 230 - [2314]
230
230
9.60
3.56
2
1272 ACSR
45
SOUTH CANTON
PICKENS 230 - [5270,6185]
230
230
27.98
1.93
2
1272 ACSR
46
SOUTH JACKSON
RANKIN 230 - [7350]
230
230
17.69
15.30
2
1272 ACSR
47
TILLATOBA
BATESVILLE 230 - [5840]
230
230
27.22
0.00
1
1780 ACSR
48
TILLATOBA
SOUTH GRENADA 230 - [2337]
230
230
19.22
15.97
2
1272 ACSR
49
TINNIN RD
GERALD ANDRUS 230 - [52304]
230
230
78.88
8.38
2
1272 ACSR
50
TINNIN RD
NORREL 230 - [2339]
230
230
6.91
0.00
1
1272 ACSR
51
TUNICA
TWINKLETOWN 230 - [5525]
230
230
23.60
2.51
2
1272 ACSR
52
TWINKLETOWN
FREEPORT 230 - [5525]
230
230
8.30
0.00
1
1272 ACSR
53
Total 230kV
46,362,352
234,210,406
280,572,758
54
HORN LAKE
ALLEN S 161 - [5960]
161
161
5.86
0.00
1
954 ACSS
55
Total 161kV
9,982
397,075
407,057
56
Total 115kV
2,026.62
40,841,776
625,264,468
666,106,244
36 TOTAL
3,028.50
123.23
73
92,697,306
923,093,567
1,015,790,873
9,879,694
5,258,880
152,890
15,291,464


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
CATLETT
SOUTH CANTON 230 KV LN 244 [2392]
3.59
11
1
1
230
230
1,530,390
7,651,948
6,121,559
15,303,897
2
GETWELL
BYHALIA 230KV LN 241 [2341]
5.88
10
1
1
230
230
1,174,199
5,870,996
4,696,797
11,741,992
44
TOTAL
9.47
21
2
2
2,704,589
13,522,944
10,818,356
27,045,889


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
AIRPORT/JACKSON
Distribution
Unattended
(a)
115.0
(b)
14.5
56.0
2
0
2
ATTALA
Distribution
Unattended
230.0
13.8
20.0
1
0
3
BELZONI
Distribution
Unattended
115.0
13.9
44.8
2
0
4
BOLTON
Distribution
Unattended
115.0
13.9
18.8
2
0
5
BOVINA
Distribution
Unattended
115.0
12.5
11.2
1
0
6
BOZEMAN ROAD
Distribution
Unattended
230.0
13.8
73.3
2
0
7
BRANDON
Distribution
Unattended
115.0
14.4
89.3
3
0
8
BRICKYARD
Distribution
Unattended
115.0
14.4
33.3
1
0
9
BROOKHAVEN
Distribution
Unattended
115.0
14.4
81.3
3
0
10
BROOKHAVEN/SOUTH
Distribution
Unattended
115.0
14.4
61.3
2
0
11
BYHALIA
Distribution
Unattended
230.0
12.5
40.0
1
0
12
BYRAM
Distribution
Unattended
115.0
14.5
66.9
2
0
13
CANTON
Distribution
Unattended
230.0
13.9
67.2
2
0
14
CANTON ROAD/JACKSON
Distribution
Unattended
115.0
14.5
66.9
2
0
15
CANTON/SOUTH
Distribution
Unattended
230.0
13.8
73.3
2
0
16
CARTHAGE (MS)
Distribution
Unattended
115.0
13.9
44.8
2
0
17
CATLETT
Distribution
Unattended
230.0
12.5
80.0
2
0
18
CENTREVILLE
Distribution
Unattended
115.0
13.9
40.0
2
0
19
CHARITY CHURCH/JACKSON
Distribution
Unattended
230.0
14.4
66.9
2
0
20
CHARLESTON
Distribution
Unattended
115.0
13.9
22.4
1
0
21
CHURCH ROAD
Distribution
Unattended
230.0
14.4
40.0
1
0
22
CLARKSDALE
Distribution
Unattended
115.0
13.9
42.4
2
0
23
CLEVELAND [MS]
Distribution
Unattended
115.0
13.9
84.0
3
0
24
CLEVELAND/SOUTH
Distribution
Unattended
115.0
13.9
56.0
2
0
25
CLINTON [MS]
Distribution
Unattended
115.0
14.5
50.4
2
0
26
CLINTON INDUSTRIAL
Distribution
Unattended
230.0
14.5
61.3
2
0
27
COLDWATER
Distribution
Unattended
115.0
13.8
66.6
2
0
28
COMO
Distribution
Unattended
115.0
13.9
20.0
2
0
29
COUNTRY CLUB/JACKSON
Distribution
Unattended
115.0
14.4
61.3
2
0
30
CRENSHAW
Distribution
Unattended
115.0
13.9
22.4
1
0
31
CRYSTAL SPRINGS
Distribution
Unattended
115.0
13.9
44.8
2
0
32
DESOTO
Distribution
Unattended
115.0
14.5
56.0
2
0
33
DREW [MS]
Distribution
Unattended
115.0
13.9
34.9
2
0
34
DURANT
Distribution
Unattended
115.0
14.5
32.5
2
0
35
EDWARDS
Distribution
Unattended
115.0
13.8
32.5
2
0
36
ELLIOTT
Distribution
Unattended
115.0
14.4
55.7
2
0
37
ELTON RD
Distribution
Unattended
115.0
13.9
20.0
1
0
38
ENID
Distribution
Unattended
230.0
14.4
20.0
1
0
39
FANNIN ROAD
Distribution
Unattended
115.0
13.9
50.4
2
0
40
FAYETTE
Distribution
Unattended
115.0
13.9
9.4
1
0
41
FERNWOOD
Distribution
Unattended
115.0
13.9
44.8
2
0
42
FLORA
Distribution
Unattended
115.0
14.5
28.0
1
0
43
FLORENCE
Distribution
Unattended
115.0
14.4
61.3
2
0
44
FLOWERS
Distribution
Unattended
115.0
13.8
40.0
2
0
45
FLOWOOD
Distribution
Unattended
115.0
14.5
66.7
2
0
46
FONDREN/JACKSON
Distribution
Unattended
115.0
14.5
78.1
3
0
47
FOREST HILL/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
48
GALLATIN STREET/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
49
GALLMAN
Distribution
Unattended
115.0
13.9
44.8
2
0
50
GEORGETOWN [MS]
Distribution
Unattended
115.0
13.8
12.5
1
0
51
GETWELL
Distribution
Unattended
230.0
13.8
80.0
2
0
52
GLEN ALLAN
Distribution
Unattended
115.0
13.9
5.0
1
0
53
GLOSTER
Distribution
Unattended
115.0
14.4
74.9
3
0
54
GRAND GULF DISTRIBUTION
Distribution
Unattended
115.0
14.5
20.0
1
0
55
GRANTS FERRY
Distribution
Unattended
230.0
13.9
70.9
2
0
56
GREENBROOK
Distribution
Unattended
115.0
14.4
94.7
3
0
57
GREENVILLE
Distribution
Unattended
115.0
13.9
56.0
2
0
58
GREENVILLE/EAST
Distribution
Unattended
115.0
13.9
42.4
2
0
59
GREENVILLE/INDUSTRIAL
Distribution
Unattended
115.0
13.9
50.4
2
0
60
GREENVILLE/MIDTOWN
Distribution
Unattended
115.0
13.9
44.8
2
0
61
GREENVILLE/NORTH
Distribution
Unattended
115.0
14.5
94.6
3
0
62
GREENVILLE/SOUTHEAST
Distribution
Unattended
115.0
13.9
28.0
1
0
63
GREENWOOD
Distribution
Unattended
115.0
13.9
44.8
2
0
64
GRENADA
Distribution
Unattended
115.0
13.9
78.4
3
0
65
GRENADA/SOUTH
Distribution
Unattended
230.0
13.9
50.4
2
0
66
HAINING ROAD
Distribution
Unattended
115.0
13.9
50.4
2
0
67
HAZLEHURST
Distribution
Unattended
115.0
13.9
50.4
2
0
68
HENDERSON ROAD
Distribution
Unattended
230.0
13.8
80.0
2
0
69
HERNANDO
Distribution
Unattended
115.0
13.9
83.2
2
0
70
HOLLANDALE
Distribution
Unattended
115.0
13.9
50.4
2
0
71
HORN LAKE
Distribution
Unattended
230.0
14.5
100.2
3
0
72
HOY ROAD
Distribution
Unattended
230.0
13.9
67.2
2
0
73
INDIANOLA 115 SUB
Distribution
Unattended
115.0
13.9
56.0
2
0
74
INVERNESS
Distribution
Unattended
115.0
13.9
32.5
2
0
75
JACKSON/EAST
Distribution
Unattended
115.0
13.9
100.5
3
0
76
JACKSON/NORTH
Distribution
Unattended
115.0
13.9
72.8
3
0
77
JACKSON/NORTHEAST
Distribution
Unattended
115.0
13.9
62.4
3
0
78
JACKSON/NORTHWEST
Distribution
Unattended
115.0
14.5
56.0
2
0
79
JACKSON/SOUTH
Distribution
Unattended
230.0
13.9
67.2
2
0
80
JACKSON/SOUTHWEST
Distribution
Unattended
115.0
13.9
44.8
2
0
81
JACKSON/TREATMENT PLANT
Distribution
Unattended
115.0
4.2
12.5
1
0
82
JACKSON/WATERWORKS
Distribution
Unattended
14.0
83
JACKSON/WEST
Distribution
Unattended
115.0
13.9
56.0
2
0
84
JOHNS MANVILLE
Distribution
Unattended
115.0
14.4
61.3
2
0
85
JONESTOWN
Distribution
Unattended
115.0
13.8
10.5
1
0
86
KINGSWOOD/JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
87
KOSCIUSKO
Distribution
Unattended
115.0
14.4
68.0
2
0
88
LAKE CASTLE
Distribution
Unattended
230.0
14.5
66.7
2
0
89
LARSON ST/JACKSON
Distribution
Unattended
115.0
14.5
33.6
1
0
90
LELAND
Distribution
Unattended
115.0
14.5
45.8
2
0
91
LEXINGTON
Distribution
Unattended
115.0
13.9
34.9
2
0
92
LIBERTY
Distribution
Unattended
115.0
13.9
22.5
2
0
93
LIVINGSTON ROAD/JACKSON
Distribution
Unattended
115.0
14.4
62.4
2
0
94
LUCKNEY
Distribution
Unattended
230.0
13.9
67.2
2
0
95
LULA
Distribution
Unattended
115.0
13.9
20.0
1
0
96
MADISON
Distribution
Unattended
115.0
13.8
40.0
1
0
97
MAGEE
Distribution
Unattended
115.0
14.5
50.4
2
0
98
MARKS
Distribution
Unattended
115.0
13.9
44.8
2
0
99
MCCOMB
Distribution
Unattended
115.0
13.9
61.3
2
0
100
MCCOMB/WEST
Distribution
Unattended
115.0
13.9
50.4
2
0
101
MEADVILLE
Distribution
Unattended
115.0
13.9
20.0
1
0
102
MEDICAL CENTER/JACKSON
Distribution
Unattended
115.0
13.9
67.2
2
0
103
MENDENHALL
Distribution
Unattended
115.0
14.5
44.8
2
0
104
MIAMI STREET/JACKSON
Distribution
Unattended
115.0
14.4
33.3
1
0
105
MIDNIGHT
Distribution
Unattended
115.0
13.9
27.4
2
0
106
MILL STREET
Distribution
Unattended
115.0
13.8
80.0
2
0
107
MONUMENT STREET/JACKSON
Distribution
Unattended
115.0
14.5
76.0
3
0
108
MOORHEAD
Distribution
Unattended
115.0
14.5
48.0
2
0
109
MORTON
Distribution
Unattended
115.0
14.4
33.3
1
0
110
NATCHEZ
Distribution
Unattended
115.0
14.4
61.3
2
0
111
NATCHEZ/INDUSTRIAL PARK
Distribution
Unattended
115.0
14.5
55.7
2
0
112
NATCHEZ/SOUTH
Distribution
Unattended
115.0
13.9
50.4
2
0
113
NESBIT
Distribution
Unattended
115.0
14.4
55.7
2
0
114
NEW HEBRON
Distribution
Unattended
115.0
13.8
10.5
1
0
115
NORTHPARK
Distribution
Unattended
230.0
14.4
66.3
2
0
116
NORTHSIDE DRIVE/JACKSON
Distribution
Unattended
230.0
13.9
56.0
2
0
117
PELAHATCHIE
Distribution
Unattended
115.0
14.5
22.4
1
0
118
PICKENS
Distribution
Unattended
230.0
13.9
28.5
2
0
119
PLUM POINT
Distribution
Unattended
115.0
14.5
106.7
3
0
120
PORT GIBSON
Distribution
Unattended
115.0
13.9
68.0
2
0
121
RALEIGH
Distribution
Unattended
115.0
13.9
10.5
1
0
122
RANKIN
Distribution
Unattended
230.0
14.4
61.3
2
0
123
RANKIN INDTRL./JACKSON
Distribution
Unattended
115.0
13.9
56.0
2
0
124
RAYMOND
Distribution
Unattended
115.0
14.5
56.0
2
0
125
REX BROWN 115 SWYD
Distribution
Unattended
115.0
13.8
40.0
1
0
126
RIDGELAND
Distribution
Unattended
115.0
14.5
66.6
2
0
127
ROBINSON ROAD/JACKSON
Distribution
Unattended
230.0
13.9
56.0
2
0
128
ROBINSONVILLE
Distribution
Unattended
230.0
34.5
133.3
3
0
129
ROLLING FORK
Distribution
Unattended
115.0
13.9
34.9
2
0
130
ROSEDALE [MS]
Distribution
Unattended
115.0
13.9
34.9
2
0
131
ROXIE
Distribution
Unattended
115.0
14.4
10.5
1
0
132
RULEVILLE
Distribution
Unattended
115.0
13.9
42.4
2
0
133
SARDIS
Distribution
Unattended
115.0
13.8
40.0
2
0
134
SCHLATER
Distribution
Unattended
115.0
13.9
21.9
2
0
135
SENATOBIA
Distribution
Unattended
115.0
14.4
73.3
2
0
136
SHELBY
Distribution
Unattended
115.0
13.9
20.9
2
0
137
SILVER CREEK
Distribution
Unattended
115.0
13.9
50.4
2
0
138
SPENCER POTASH
Distribution
Unattended
115.0
13.9
22.4
1
0
139
SPRING RIDGE ROAD
Distribution
Unattended
115.0
13.9
33.6
1
0
140
STAR
Distribution
Unattended
115.0
13.9
22.5
2
0
141
STRINGTOWN
Distribution
Unattended
115.0
13.9
12.5
1
0
142
SUNNYBROOK
Distribution
Unattended
115.0
13.8
40.0
1
0
143
TERRY
Distribution
Unattended
115.0
13.8
51.9
2
0
144
TINNIN ROAD
Distribution
Unattended
230.0
13.8
40.0
1
0
145
TUNICA
Distribution
Unattended
115.0
13.9
22.4
1
0
146
TWINKLETOWN
Distribution
Unattended
230.0
14.4
33.3
1
0
147
TYLERTOWN
Distribution
Unattended
115.0
13.9
37.5
3
0
148
UTICA
Distribution
Unattended
115.0
13.9
30.5
2
0
149
VICKSBURG
Distribution
Unattended
115.0
13.9
42.4
2
0
150
VICKSBURG/EAST
Distribution
Unattended
115.0
13.9
42.4
2
0
151
VICKSBURG/NORTH
Distribution
Unattended
115.0
13.9
70.4
3
0
152
VICKSBURG/OPENWOOD
Distribution
Unattended
115.0
13.8
33.3
1
0
153
VICKSBURG/SOUTH
Distribution
Unattended
115.0
13.9
42.4
2
0
154
VICKSBURG/SOUTHEAST
Distribution
Unattended
115.0
13.9
28.0
1
0
155
VICKSBURG/WEST
Distribution
Unattended
115.0
14.4
53.0
2
0
156
WALLS
Distribution
Unattended
115.0
13.9
9.4
1
0
157
WEBB
Distribution
Unattended
115.0
13.9
16.9
2
0
158
WESSON
Distribution
Unattended
115.0
14.5
28.0
1
0
159
WHITFIELD
Distribution
Unattended
115.0
13.9
22.4
1
0
160
WINONA
Distribution
Unattended
115.0
13.9
44.8
2
0
161
WOODVILLE [MS]
Distribution
Unattended
115.0
13.9
12.5
1
0
162
WYNNDALE
Distribution
Unattended
115.0
13.8
80.0
2
0
163
YANDELL RD
Distribution
Unattended
230.0
13.9
100.3
3
0
164
YAZOO CITY SS
Distribution
Unattended
115.0
13.9
12.5
1
0
165
ATTALA
Transmission
Unattended
230.0
120.0
(c)
13.8
391.8
1
0
166
ATTALA PLANT
Transmission
Unattended
500.0
167
BATESVILLE [MS]
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
168
BAXTER WILSON SES SWYD
Transmission
Unattended
500.0
115.0
1176.0
2
0
169
BEECH GROVE SS
Transmission
Unattended
115.0
170
BOWLING GREEN SS
Transmission
Unattended
115.0
171
CHOCTAW
Transmission
Unattended
500.0
172
DELTA SWYD
Transmission
Unattended
115.0
173
ELLIOTT SS
Transmission
Unattended
115.0
174
FRANKLIN EHV
Transmission
Unattended
500.0
115.0
13.8
1120.0
2
0
175
FREEPORT
Transmission
Unattended
500.0
230.0
13.9
975.0
1
0
176
GERALD ANDRUS SES SWYD
Transmission
Unattended
230.0
120.0
13.9
392.0
1
0
177
GETWELL
Transmission
Unattended
230.0
115.0
13.8
392.0
1
0
178
GRAND GULF TRANSMISSION
Transmission
Unattended
500.0
179
GRENADA/SOUTH
Transmission
Unattended
230.0
115.0
500.0
1
0
180
HARPER
Transmission
Unattended
115.0
181
HORN LAKE
Transmission
Unattended
230.0
161.0
13.8
1027.0
3
0
182
INDIANOLA 230/115 SUB
Transmission
Unattended
230.0
120.0
391.8
1
0
183
JACKSON/SOUTH
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
184
JONESTOWN SS
Transmission
Unattended
115.0
185
LAKEOVER EHV
Transmission
Unattended
500.0
230.0
1215.0
2
0
186
MCADAMS EHV
Transmission
Unattended
500.0
230.0
1500.0
2
0
187
MINTER CITY SS
Transmission
Unattended
115.0
188
MOON LAKE SS
Transmission
Unattended
230.0
189
NATCHEZ SWYD
Transmission
Unattended
115.0
190
PICKENS
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
191
RANKIN
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
192
RAY BRASWELL EHV
Transmission
Unattended
500.0
230.0
13.9
2073.0
4
0
193
REX BROWN 230 SWYD
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
194
SHELBY SS
Transmission
Unattended
115.0
195
TILLATOBA
Transmission
Unattended
230.0
120.0
13.9
391.8
1
0
196
TUNICA 230/115 SUB
Transmission
Unattended
230.0
120.0
391.8
1
0
197
VICKSBURG/EAST SS
Transmission
Unattended
115.0
198
WOLF CREEK
Transmission
Unattended
500.0
199
YAZOO CITY MUNICIPAL SS
Transmission
Unattended
115.0
200
TotalDistributionSubstationMember
164
201
TotalGenerationSubstationMember
0
202
TotalTransmissionSubstationMember
35
203
Total
199


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: PrimaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(b) Concept: SecondaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.
(c) Concept: TertiaryVoltageLevel
Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
(a)
See footnote for schedule details
3
(b)
See footnote for allocation method details
19
20
Non-power Goods or Services Provided for Affiliated
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42


Name of Respondent:

Entergy Mississippi, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

04/13/2023
Year/Period of Report

End of:
2022
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNonPowerGoodOrService
Non-power goods or services received from or provided to associated (affiliated) companies are reported in the schedule below by type of category, where the amount charged or credited from or to each affiliate is equal to or greater than the $250,000 threshold.                

Line No. Description of the Non-Power Good or Service Name of Associated/Affiliated Company Account Charged or Credited Amount Charged or Credited
(a) (b) (c) (d)
1 Non-power Goods or Services Provided by Affiliate
2 Support - Corporate Entergy Services, LLC 107000, 108220, 108230, 163000, 174101, 174200, 183000, 184001, 228100, 408202, 426400, 426500, 500000, 506000, 510000, 512000, 514000, 535000, 546000, 549000, 551000, 553000, 556000, 557000, 560000, 561200, 561300, 561500, 563000, 566000, 568000, 569000, 573000, 580000, 581000, 583000, 584000, 586000, 588000, 590000, 592000, 593000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 905000, 907000, 908000, 909000, 910000, 916000, 920000, 921000, 923000, 924000, 925000, 926000, 928000, 930100, 930200, 931000, 935000, 183KSL, 1840FS, 1840NC, 184EST, 4031AM, 926NS1 34,625,145 
3 Support - Distribution Entergy Services, LLC 107000, 108230, 163000, 174101, 174200, 184001, 228100, 408110, 408202, 426400, 426500, 500000, 506000, 507000, 514000, 546000, 553000, 560000, 561500, 566000, 567000, 568000, 580000, 581000, 583000, 584000, 585000, 586000, 587000, 588000, 589000, 590000, 592000, 593000, 594000, 595000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 908000, 909000, 913000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 181CPD, 183KSL, 1840FS, 1840NC, 184EPC, 184EST, 926NS1 23,619,103 
4 Support - External Affairs and Legal Entergy Services, LLC 107000, 174101, 183000, 228100, 408110, 426100, 426400, 426500, 431006, 500000, 506000, 514000, 549000, 566000, 580000, 588000, 908000, 909000, 910000, 920000, 921000, 923000, 925000, 926000, 928000, 930100, 930200, 931000, 935000, 183KSL, 926NS1 6,949,200 
5 Support - Finance and Accounting Entergy Services, LLC 107000, 163000, 184001, 228100, 426400, 426500, 560000, 580000, 901000, 903002, 920000, 921000, 923000, 924000, 925000, 926000, 928000, 930100, 930200, 931000, 935000, 181CPD, 183KSL, 1840FS 7,710,692 
6 Support - Fossil Entergy Services, LLC 107000, 108220, 163000, 174101, 228100, 408110, 500000, 506000, 507000, 510000, 512000, 513000, 514000, 535000, 546000, 549000, 550000, 551000, 552000, 553000, 556000, 557000, 561200, 566000, 920000, 921000, 923000, 926000, 928000, 930200, 931000, 935000, 183KSL, 5612BA 11,123,057 
7 Support - HRA/Administration Entergy Services, LLC 107000, 108220, 108230, 163000, 174101, 174200, 183000, 184001, 228100, 408110, 408202, 419000, 421000, 426100, 426300, 426400, 426500, 431000, 454000, 500000, 514000, 546000, 553000, 560000, 563000, 566000, 568000, 580000, 583000, 588000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 935000, 183KSL, 1840FS, 1840NC, 184EST, 926NS1 28,397,066 
8 Support - Information Technology Entergy Services, LLC 107000, 108220, 174101, 174200, 184001, 228100, 408110, 408202, 426100, 426400, 426500, 454000, 500000, 506000, 514000, 539000, 549000, 560000, 561200, 566000, 567000, 568000, 569200, 573000, 580000, 588000, 589000, 598000, 903001, 910000, 920000, 921000, 923000, 926000, 930200, 931000, 935000 30,063,253 
9 Support - President/CEO Entergy Services, LLC 107000, 163000, 174101, 184001, 408110, 408202, 426100, 426400, 426500, 506000, 514000, 546000, 549000, 560000, 568000, 580000, 901000, 902000, 903001, 903002, 905000, 907000, 908000, 909000, 910000, 911000, 912000, 913000, 916000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 935000, 183KSL 16,940,441 
10 Support - Supply Chain Entergy Services, LLC 107000, 163000, 184001, 228100, 408110, 426400, 426500, 500000, 506000, 514000, 546000, 560000, 580000, 588000, 920000, 921000, 923000, 926000, 930100, 930200, 183KSL 2,486,507 
11 Support - Transmission Entergy Services, LLC 107000, 108220, 174101, 174200, 184001, 228100, 408110, 500000, 560000, 561200, 561300, 561500, 561600, 565400, 566000, 567000, 568000, 569000, 569100, 573000, 580000, 588000, 589000, 590000, 592000, 593000, 910000, 920000, 921000, 923000, 926000, 930200 16,380,356 
12 Support - Utility Operations Entergy Services, LLC 107000, 184001, 408110, 426400, 500000, 506000, 514000, 546000, 560000, 561500, 566000, 568000, 580000, 588000, 589000, 590000, 592000, 593000, 903001, 907000, 909000, 913000, 916000, 920000, 921000, 923000, 926000, 928000, 930100, 930200, 931000, 935000 4,345,575 
13 Tax and Interest Expense Entergy Services, LLC 408110, 408122, 408142, 408152, 408155, 408156, 408158, 408165, 408202, 409112, 409114, 409148, 409149, 410101, 410120, 411110, 411120, 411430, 419000, 419011, 421000, 426100, 426300, 426400, 426500, 430000, 431000, 431003 3,181,230 
14 Inventory Transfers of Materials and Supplies. Entergy Arkansas, LLC 107000, 108230, 154PAS, 163000, 174101, 228400, 568000, 570000, 580000, 590000, 593000, 921000 11,304,756 
15 Loaned Labor and Associated Loaders Entergy Arkansas, LLC 107000, 108230, 408110, 514000, 549000, 588000, 592000, 593000, 594000, 903002, 926000, 926NS1 127,125 
16 Storm Support Entergy Arkansas, LLC 174101, 228100 25,844 
17 Inventory Transfers of Materials and Supplies. Entergy Louisiana, LLC 107000, 108230, 154PAS, 163000, 580000, 586000, 590000 1,026,046 
18 Loaned Labor and Associated Loaders Entergy Louisiana, LLC 107000, 108220, 1840FS, 408110, 506000, 514000, 549000, 568000, 582000, 583000, 586000, 587000, 592000, 593000, 594000, 596000, 598000, 902000, 920000, 926000, 926NS1 196,401 
19 Storm Support Entergy Louisiana, LLC 174101 5,069 
20 Inventory Transfers of Materials and Supplies. Entergy Texas, Inc 154PAS, 163000, 590000 781,026 
21 Loaned Labor and Associated Loaders Entergy Texas, Inc 107000, 408110, 583000, 586000, 592000, 593000, 594000, 595000, 598000, 902000, 926000, 926NS1 133,852 
22 Storm Support Entergy Texas, Inc 174101 163,723 
23 Non-power Goods or Services Provided for Affiliate
24 Inventory Transfers of Materials and Supplies. Entergy Arkansas, LLC 108230, 154PAS, 163000, 583000 985,303 
25 Loaned Labor and Associated Loaders Entergy Arkansas, LLC 107000, 408110, 4265OT, 4265TX, 551000, 570000, 580000, 582000, 586000, 592000, 593000, 594000, 596000, 597000, 598000, 902000, 926000, 926NS1 19,375 
26 Storm Support Entergy Arkansas, LLC 174101, 228100, 4265OT, 4265TX 386,995 
27 Inventory Transfers of Materials and Supplies. Entergy Louisiana, LLC 107000, 154PAS, 163000, 174101, 228400, 568000, 570000 4,234,631 
28 Loaned Labor and Associated Loaders Entergy Louisiana, LLC 107000, 228400, 408110, 500000, 570000, 584000, 585000, 586000, 587000, 588000, 592000, 593000, 594000, 596000, 598000, 902000, 903001, 920000, 926000, 926NS1 155,875 
29 Storm Support Entergy Louisiana, LLC 174101 4,326 
30 Inventory Transfers of Materials and Supplies. Entergy Texas, Inc 107000, 154PAS, 163000 395,825 
31 Loaned Labor and Associated Loaders Entergy Texas, Inc 107000, 408110, 4265OT, 4265TX, 570000, 586000, 587000, 593000, 594000, 598000, 902000, 926000, 926NS1 14,758 
32 Storm Support Entergy Texas, Inc 174101 28 
(b) Concept: DescriptionOfNonPowerGoodOrService
Listed below are the allocation factors used to allocate costs to the affiliate.
Note: Where no allocation factor is provided for the non-power goods or services listed on Schedule 429, the costs associated with those goods and services were directly charged and not allocated.

Description of the Non-Power Good or Service Cost Allocator(s)
Entergy Services
Support - Corporate APPSUNIX, APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, BNKACCTA, CAPACCGT, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, EMPXENUC, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, GWHOPCPE, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCPSPXNC, SCRSPALL, SCTDSPAL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
Support - Distribution APPSUPAL, APTRNALL, ASSTSALL, ASTREGOP, BNKACCTA, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DSTLNALL, EMPLFRAN, EMPLOREG, EMPLOYAL, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, SCDSPALL, SCFSPALL, SCLDTMLS, SCPSPALL, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - External Affairs and Legal APTRNALL, ASSTSALL, ASSTSREG, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLTRAN, EMPLUTOP, GENLDREG, GENLEDAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRUTOPN, LVLSVCAL, MACCTALL, OWNISFI, PCNUMALL, PKLOADAL, PRCHKALL, RECDMGNT, SCDSPALL, SCMATRAN, SCPSPALL, SCRSPALL, SCTSPALL, SQFTALLC, TRANSPND, TRSBLNOP
Support - Finance and Accounting APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, DSTLNALL, EMPLOREG, EMPLOYAL, EMPLPRES, GENLDREG, GENLEDAL, GPASSTTN, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, NETPPEAL, OWNISFI, PCNUMALL, PKLOADAL, PRCHKALL, SCMATRAN, SCPSPALL, SCRSPALL, SQFTALLC, TRANSPND, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
Support - Fossil ARTRNALL, ASSTSALL, ASTREGOP, CAPACCGT, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOFOS, EMPLOREG, EMPLOYAL, GENLEDAL, GPASSTTN, GWHOPCPE, ITSPENDA, LBRCORPT, LBRSUPCN, PKLOADAL, SCFSPALL, SCMATRAN, SCPSPALL, SCRSPALL, SQFTALLC, TELPHALL, TRANSPND, TRSBLNOP, VEHCLFOS
Support - HRA/Administration APPSUNIX, APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, BNKACCTA, CAPACCGT, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, EMPXENUC, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, GWHOPCPE, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCPSPXNC, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, UNPOWSAL, VEHCLFOS, VEHCLUSG
Support - Information Technology APPSMVSX, APPSUNIX, APPSUPAL, APPSWINT, APTRNALL, ASSTSALL, ASSTSREG, CAPACCGT, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOREG, EMPLOYAL, EMPXENUC, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, GWHOPCPE, ITSPENDA, LBRBILAL, LBRINFOR, LBRLEGAL, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCMATRAN, SCPSPALL, SCRSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLUSG
Support - President/CEO APPSUPAL, APTRNALL, ASSTSALL, ASSTSREG, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, CUSTOEAM, EMPLOYAL, GPASSTTN, ITSPENDA, LBRBILAL, LBRCORPT, LBRUTOPN, MACCTALL, PCNUMALL, PKLOADAL, SCFSPALL, SCPSPALL, SCRSPALL, SQFTALLC, TELPHALL, TRSBLNOP, VEHCLUSG
Support - Supply Chain ASSTSALL, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, EMPLOYAL, GPASSTAL, GPASSTDS, GPASSTTN, LBRCORPT, LBRSUPCN, NETPPEAL, PKLOADAL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCPSPXNC, SCRSPALL, SCTDSPAL, SCTSPALL, TRANSPND
Support - Transmission ASSTSALL, ASTREGOP, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTEGOP, CUSTOEAM, DSTLNALL, EMPLOYAL, EMPLTRAN, GPASSTAL, GPASSTTN, ITSPENDA, LBRBILAL, LBRCORPT, LVLSVCAL, NETPPEAL, PCNUMXNR, PKLOADAL, SCDSPALL, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLUSG
Support - Utility Operations APPSUPAL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOREG, EMPLOYAL, EMPLTRAN, EMPLUTOP, GENLDREG, GENLEDAL, GPASSTAL, GPASSTDS, GPASSTTN, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRLEGAL, LBRUTOPN, LVLSVCAL, MACCTALL, PCNUMALL, PKLOADAL, PRCHKALL, SCRSPALL, TRALINOP, TRASUBOP, TRSBLNOP, VEHCLUSG
Tax and Interest Expense APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, BNKACCTA, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLTRAN, EMPLUTOP, GENLDREG, GENLEDAL, GPASSTAL, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, OWNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCMATRAN, SCPSPALL, SCPSPXNC, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRASUBOP, TRSBLNOP, UNPOWSAL

Cost Allocator Descriptions

Cost Allocator Cost Allocator Title Cost Allocator Description
Entergy Services
APPSMVSX Server and Mainframe Usage - MVS Based on mainframe usage
APPSUNIX Server and Mainframe Usage - UNIX Based on the UNIX server usage
APPSUPAL Server and Mainframe Usage - Composite Based on weighted composite of UNIX and NT servers and mainframe usage
APPSWINT Server and Mainframe Usage - NTS Based on WINTEL server usage
APTRNALL Accounts Payable Transactions Based on a twelve-month number of accounts payable transactions processed
ARTRNALL Accounts Receivable Invoices Based on a twelve-month number of accounts receivable transactions processed
ASSTSALL Total Assets Based on the total assets at period end
ASSTSREG Total Assets - Regulated BU's Based on total assets at period end for all regulated Business Units
ASTREGOP Total Assets - Regulated BUs, excluding SERI Based on total assets at period end for all regulated Business Units, excluding SERI
BNKACCTA Bank Accounts Based on the number of bank accounts at period end
CAPACCGT System Capacity - CCGT Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously (CCGT)
CAPAOPCO System Capacity Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously
CAPXCOPC System Capacity - Excluding Coal and Nuclear Based on the power level, in kilowatts, that could be achieved if all non-coal and non-nuclear generating units were operating at maximum capability simultaneously
COMCLAIM Workers' Compensation Claims Based on number of open workers' compensation claims
CUSEGAMI Customers - AMI Only Based on a twelve-month average number of electric-only, gas-only, and dual (electric and gas) customers derived from the number of gas-only customers provided by Gas Operations. This method should only be used to allocate Advanced Metering Infrastructure (AMI) deployment infrastructure expense. (Does not include meter hardware purchases)
CUSEGXTX Electric and Gas Customers - Excluding ETI Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, municipal, and general business customers, excluding ETI
CUSEOPCO Electric Customers Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers
CUSTCALL Customer Call Centers Based on a twenty-four month average of customer calls
CUSTEGOP Electric and Gas Customers Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, and municipal general business customers
CUSTEXTX Electric Customers - Excluding ETI Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI, ELA, EMI, and ENOI
CUSTOEAM Electric Customers - EAI and EMI Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI and EMI
DSTLNALL Distribution Line Miles Based on the number of miles of distribution lines
EMPLFRAN Employees - Franchise Operations Based on the number of full-time and part-time employees within Franchise Operations
EMPLOCSS Employees - Customer Support Services Based on the number of full-time and part-time employees within Customer Support Service
EMPLOFOS Employees - Fossil Plant Operations Based on the number of full-time and part-time employees within Fossil Plant Operations
EMPLOREG Full-Time and Part-Time Employees - EAI, ELA, EMI, ENOI, SERI, ETI and ESI Based on the number of full-time and part-time employees at period end for EAI, ELA, EMI, ENOI, SERI, ETI and ESI
EMPLOYAL Full-Time and Part-Time Employees Based on the number of full-time and part-time employees at period end
EMPLPRES Employees - State President Based on the number of full-time and part-time employees within State President Organizations
EMPLTRAN Employees - Transmission Based on the number of full-time and part-time employees within Transmission
EMPLUTOP Employees - Utility Operations Based on the number of full-time and part-time employees within Utility Operations
EMPXENUC Employees - Excluding ENUC Based on the number of full-time and part-time employees at period end, excluding ENUC
GENLDREG General Ledger Transactions - Regulated Companies Based on general ledger transactions for regulated companies
GENLEDAL General Ledger Transactions Based on general ledger transactions
GPASSTAL Gross Utility Plant Assets - OpCos (EAM use only) Based on the gross value of utility plant assets at period end for all Entergy Operating Company - for EAM (Enterprise Asset Management) use only
GPASSTDS Gross Electric Distribution Utility Plant Assets – Operating Companies Based on the gross value of electric distribution utility plant assets at period end for all Entergy Operating Companies
GPASSTTN Gross Electric Transmission Utility Plant Assets – Operating Companies Based on the gross value of electric transmission utility plant assets at period end for all Entergy Operating Companies
GWHOPCPE GWH Energy Sales Based on energy sales to ultimate customers
INSPREAL Insurance Premiums Based on non-nuclear insurance premiums
ITSPENDA Information Technology Total Spending Based on Information Technology twelve-month total spending
LBRBILAL ESI Labor Costs Billed Based on total labor dollars billed to each Client Company by ESI
LBRCOMUN ESL Labor Billed - Communications Based on total labor dollars billed to each company by ESL for the Communications function
LBRCORPT ESI Labor Billed - Corporate Based on total labor dollars billed to each company by ESI for the Corporate function
LBRFDPOL ESI Labor Billed - Federal Policy, Regulatory and Governmental Affairs Based on total labor dollars billed to each company by ESI for the Federal Policy, Regulatory and Governmental Affairs function
LBRFINAN ESI Labor Billed - Finance Based on total labor dollars billed to each company by ESI for the Finance function
LBRINFOR ESI Labor Billed - IT Based on total labor dollars billed to each company by ESI for the IT function
LBRLEGAL ESL Labor Billed - Legal Based on total labor dollars billed to each company by ESL for the Legal function
LBRSUPCN ESI Labor Billed - Supply Chain Based on total labor dollars billed to each company by ESI for the Supply Chain function
LBRUTOPN ESI Labor Billed - Utility Operations Based on total labor dollars billed to each company by ESI for the Utility Operations function
LVLSVCAL ESI Service Level Based on ESI total billings to each Client Company
MACCTALL Managed Accounts Based on number of retail managed accounts
NETPPEAL Net Property, Plant, and Equipment Based on the net book value of all companies with property, plant and equipment - excluding natural gas and nuclear fuel
OWNISFI Percentage Ownership - SFI Based on the percentage ownership of SFI
PCNUMALL Number of PC's Based on the number of PC's within each Business Unit
PCNUMXNR Number of PC's - Excluding Non-Regulated BU's Based on the number of PC's within each regulated Business Unit at EAI, ELA, EMI, ENOI, SERI, ETI and ESI
PKLOADAL Peak Load Ratio Based on the ratio of each Client Company’s load to the peak load at time of all companies peak load. The calculation of Peak Load Ratio is performed using a twelve-month rolling average of the coincident peaks.
PRCHKALL Payroll Checks Issued Based on the number of payroll checks issued for each Business Unit
RADIOALL Radio Usage Based on usage of Entergy's 2-way radio system
RECDMGNT Records Management Based on the number of full-time and part time employees at period end, excluding the Nuclear function using records management services
SCDSPALL Supply Chain Spending - Distribution Based on Supply Chain Procurement Total Spending for the Distribution Function
SCFSPALL Supply Chain Spending - Fossil Based on Supply Chain Procurement Total Spending for the Fossil Function
SCLDTMLS Supply Chain - Labor Dollars Based on Supply Chain Labor Dollars for the Transformer, Meter, and Light Shops
SCMATRAN Supply Chain Transactions in Passport Based on the number of Supply Chain materials transactions for each Business Unit in Passport
SCPSPALL Supply Chain Total Spending Based on Supply Chain's Procurement Total Spending
SCPSPXNC Supply Chain Spending - Excluding Nuclear Based on Supply Chain Procurement Total Spending, excluding Nuclear for twelve months
SCRSPALL Supply Chain Spending - Regulated Companies Based on Supply Chain Procurement Total Spending for the Regulated Companies
SCTDSPAL Supply Chain Spending - Distribution and Transmission Based on Supply Chain's Procurement Total Spending for Distribution and Transmission functions
SCTSPALL Supply Chain Spending - Transmission Based on Supply Chain's Procurement Total Spending for Transmission
SQFTALLC Square Footage - All Companies Based on square footage for all Business Units
TELPHALL Number of Telephones Based on number of telephones within each Business Unit
TRALINOP Transmission Line Miles Based on the number of miles of transmission lines, weighted for design voltage (Voltage < 400kv = 1; Voltage >400kv =2)
TRANSPND Transmission Budgeted Capital Expenditures Based on Transmission Budgeted Capital Expenditures
TRASUBOP Transmission Substations Based on the number of high voltage substations weighted for Voltage (Voltage < 500kv = 1; Voltage >= 500kv = 2)
TRSBLNOP Transmission Line Miles/Substation Based on two components: Transmission Line Miles (30% weighting) and the Number of High Voltage Substations (70% weighting)
UNPOWSAL Unit Power Sales Agreement Based on allocation factors in connection with Entergy's Unit Power Sales Agreement. This allocates capacity, energy, and related costs from GG1.
VEHCLFOS Number of Vehicles - Fossil Based on the number of vehicles owned or leased by each Business Unit for the Fossil function only
VEHCLUSG Number of Vehicles - Excluding Fossil and Nuclear Based on the number of vehicles owned or leased by each Business Unit that participates in the usage based transportation allocation, excluding Fossil and Nuclear
XBRL Instance File
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